CN104563927B - A kind of wellbore stability method and experimental facilities being applicable under balance pressure drilling - Google Patents
A kind of wellbore stability method and experimental facilities being applicable under balance pressure drilling Download PDFInfo
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- CN104563927B CN104563927B CN201410721094.1A CN201410721094A CN104563927B CN 104563927 B CN104563927 B CN 104563927B CN 201410721094 A CN201410721094 A CN 201410721094A CN 104563927 B CN104563927 B CN 104563927B
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- 238000005553 drilling Methods 0.000 title claims abstract description 168
- 238000000034 method Methods 0.000 title claims abstract description 26
- 239000012530 fluid Substances 0.000 claims abstract description 143
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 58
- 230000000694 effects Effects 0.000 claims abstract description 37
- 239000012528 membrane Substances 0.000 claims abstract description 36
- 238000012360 testing method Methods 0.000 claims abstract description 34
- 239000000126 substance Substances 0.000 claims abstract description 22
- 239000007788 liquid Substances 0.000 claims abstract description 21
- 239000011148 porous material Substances 0.000 claims abstract description 15
- 238000005381 potential energy Methods 0.000 claims abstract description 13
- 239000008398 formation water Substances 0.000 claims abstract description 11
- 239000011435 rock Substances 0.000 claims description 48
- 238000002347 injection Methods 0.000 claims description 25
- 239000007924 injection Substances 0.000 claims description 25
- 239000003822 epoxy resin Substances 0.000 claims description 17
- 229920000647 polyepoxide Polymers 0.000 claims description 17
- 238000007789 sealing Methods 0.000 claims description 17
- 238000003860 storage Methods 0.000 claims description 12
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 12
- 238000001179 sorption measurement Methods 0.000 claims description 10
- 230000000087 stabilizing effect Effects 0.000 claims description 9
- 230000006641 stabilisation Effects 0.000 claims description 3
- 238000011105 stabilization Methods 0.000 claims description 3
- 238000005303 weighing Methods 0.000 claims description 3
- 238000005516 engineering process Methods 0.000 abstract description 13
- 239000000706 filtrate Substances 0.000 abstract description 6
- 230000009286 beneficial effect Effects 0.000 abstract description 2
- 238000002474 experimental method Methods 0.000 description 7
- 238000004364 calculation method Methods 0.000 description 6
- 239000000463 material Substances 0.000 description 4
- 230000008859 change Effects 0.000 description 3
- 230000003204 osmotic effect Effects 0.000 description 3
- 238000011160 research Methods 0.000 description 3
- 238000012546 transfer Methods 0.000 description 3
- 230000005540 biological transmission Effects 0.000 description 2
- 230000007547 defect Effects 0.000 description 2
- 238000013461 design Methods 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 230000001788 irregular Effects 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 230000002035 prolonged effect Effects 0.000 description 2
- 238000002791 soaking Methods 0.000 description 2
- 241001269238 Data Species 0.000 description 1
- 241000053227 Themus Species 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 238000005056 compaction Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 230000008878 coupling Effects 0.000 description 1
- 238000010168 coupling process Methods 0.000 description 1
- 238000005859 coupling reaction Methods 0.000 description 1
- 230000001186 cumulative effect Effects 0.000 description 1
- 238000007599 discharging Methods 0.000 description 1
- 230000009545 invasion Effects 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 238000000691 measurement method Methods 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 238000004451 qualitative analysis Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/005—Testing the nature of borehole walls or the formation by using drilling mud or cutting data
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Abstract
The present invention relates to a kind of the wellbore stability method and the experimental facilities that are applicable under balance pressure drilling.Comprise the following steps: (one) determines the formation water activity of mud shale; (2) formation pore pressure to be drilled is determined; (3) fo pination temperature; (4) membrane efficiency experimental apparatus for testing is utilized to measure stratum membrane efficiency; (5) according to drilling well liquid columnpressure and well depth determination drilling fluid density; (6) if determine drilling fluid density, then determine that drilling well liquid columnpressure is under-voltage value with the difference between strata pressure, according to total potential-energy balance principle, utilize under-voltage value to obtain difference in chemical potential, then according to difference in chemical potential and formation water activity determination drilling fluid activity; (7) wellbore stability is kept according to determination result adjustment drilling fluid density or activity.Beneficial effect: taken into full account the effect of chemical potential, provides drilling fluid density when keeping the total potential-energy balance in stratum accurately, effectively prevents drilling fluid filtrate invaded formation, improve borehole wall stability, enhance the application of under-balanced drilling technology.
Description
Technical Field
The invention relates to an oil field drilling method, in particular to a well wall stabilizing method and an experimental device suitable for under-balanced drilling.
Background
Underbalanced drilling refers to a drilling technique in which the circulation pressure of the drilling fluid (including the fluid column pressure and the circulation back pressure) during drilling is lower than the pore pressure of the formation, so that the fluid in the formation enters the wellbore in a controlled manner and is circulated to the surface. The underbalanced drilling technology is adopted, so that the mechanical drilling speed can be improved, the service life of a drill bit is prolonged, the leakage and differential pressure sticking are reduced or eliminated, the drilling efficiency is improved, and the direct drilling cost is reduced; and a new production zone can be found, so that the soaking time of the oil-gas layer is reduced, and the invasion damage of the drilling fluid to the stratum is reduced or eliminated, thereby effectively protecting the oil-gas layer and improving the cumulative yield of the reservoir.
Therefore, the underbalanced drilling technology is widely applied at home and abroad. From 2007, the number of underbalanced wells drilled in the United states is over 12000 per year, accounting for about 26% of the total number of wells drilled per year, and the technology has become the first choice for reservoir opening; the underbalanced drilling technology is widely popularized in recent years in China, and as long as 2012 is reached, the application effect is obvious when the number of 1017 underbalanced wells is completed in China; however, the problem of borehole wall stability in underbalanced drilling has not been solved effectively, and has become a major obstacle restricting the technical development of underbalanced drilling.
Borehole instability of underbalanced drilling is mostly caused in shale intervals. After the shale stratum is opened, pressure transfer and material exchange can occur after the drilling fluid contacts with the stratum, so that stratum pressure change and rock strength reduction are caused, and the borehole wall is unstable. Formation pressure transfer and material exchange are controlled primarily by two factors: (1) the hydraulic potential difference between the drilling fluid column pressure and the formation pore pressure; (2) the chemical potential difference between the drilling fluid filtrate and the formation fluid. At present, the drilling fluid density of underbalanced drilling is designed according to stratum collapse pressure, stratum pore pressure and the pressure bearing capacity of equipment, only the influence of hydraulic potential difference on stratum pressure transmission and material exchange is considered, namely, the liquid column pressure is kept to be smaller than the stratum pore pressure, and the influence of chemical potential on stratum pressure transmission and material exchange is not considered, so that drilling filtrate invades the stratum under the action of the chemical potential, and underground complex conditions such as borehole wall collapse, stuck drilling and the like are caused. Therefore, it is only possible to keep the hydraulic and chemical potential differences between the drilling fluid and the formation fluid balanced at the same time, i.e. the total potential energy balance, to prevent the drilling fluid filtrate from invading the formation, reducing the strength of the formation, causing complex accidents and polluting the formation.
In conclusion, the traditional design method for the density of the underbalanced drilling fluid cannot be applied, and the simple and practical design method for the stability of the well wall of the underbalanced drilling well is provided based on the total potential energy balance theory and is very important for the stability of the well wall of the underbalanced drilling well.
The semi-permeable membrane efficiency tester disclosed by the utility model with the Chinese patent application number of 200720187488.9 and the shale membrane efficiency tester disclosed by the utility model with the number of 200420089356.9 both adopt an indirect measurement method for comparing the conductivity of semi-permeable membrane liquid in an equilibrium state with the known conductivity and converting the conductivity into the semi-permeable membrane efficiency, only the change of the properties of the semi-permeable membrane liquid in the equilibrium state is considered, and the influence of the properties of shale and the pore structure on osmotic pressure and membrane efficiency is ignored; the drilling fluid semipermeable membrane measuring device disclosed by the utility model with the Chinese patent application number of 200620034702.2 can only carry out the test under the normal temperature condition, can not measure the membrane efficiency under the actual formation temperature, only considers the soaking of the drilling fluid to the rock core in the drilling process, and ignores the flowing of the drilling fluid in the shaft; the development of a shale membrane efficiency tester, an oil drilling and production process, 11 th 2010, an author, Zhang rock, Zhang Xingjin, \37154, Jiechen, Wubin Zhao, Lei; by measuring the change of the resistivity of the solution at two ends of the rock core, the film forming efficiency of different drilling fluid systems is evaluated in a comparison mode, only qualitative analysis is performed, and the measurement result of the efficiency of the shale film cannot be quantitatively obtained. The new technology of the mud shale hydration-mechanics coupling simulation experiment device and the pressure transfer experiment, the new technology of the petroleum institute, 11.2005, 26.6 th volume of the experimental device and the testing technology research the oil machinery, 2006, 34 th volume, 8 th volume of the experimental device and the testing technology research the osmotic pressure and the membrane efficiency, but the experimental device can be developed only by using a regular standard core, and the experimental device can not be developed by using an irregular core and a dropping block, and is complex and inconvenient to operate and use on site.
Disclosure of Invention
The invention aims to provide a well wall stabilizing method and an experimental device suitable for underbalanced drilling aiming at the defects in the prior art, and the method can keep the well wall stable by simple equipment and operation procedures and improve the application and popularization of the underbalanced technology.
A method of borehole wall stabilization for underbalanced drilling comprising the steps of:
collecting and determining the formation water activity of the shale by using an isothermal adsorption test;
determining the pore pressure of the stratum to be drilled according to the adjacent well logging data and the formation pressure test data;
determining the formation temperature according to formation temperature data of logging while drilling, or calculating the formation temperature according to the geothermal gradient of the region;
measuring the formation membrane efficiency by using a membrane efficiency test experimental device; the membrane efficiency testing experimental device comprises a servo control injection pump (1), a constant temperature box (7), a rock core holder (8), a computer data acquisition system (19), a back pressure regulator (21) and a liquid storage box (28), wherein the rock core holder (8) is arranged in the constant temperature box (7), the servo control injection pump (1) is used for providing pressure for drilling fluid at the lower end of a rock core and providing circulating pressure for drilling fluid at the upper end of the rock core, and the back pressure regulator (21) is used for keeping the flowing pressure of the drilling fluid at the upper end of the rock core holder (8) constant; the computer data acquisition system (19) is used for acquiring and recording the pressure and the temperature in the constant temperature box (7) in real time; the core holder (8) comprises a core holder upper end cover (29), a core holder lower end cover (30), epoxy resin (9) and a sealing ring (31), the core (10) is clamped between the core holder upper end cover (29) and the core holder lower end cover (30), and the epoxy resin (9) wraps the periphery of the core to form a regular sample;
if certain drilling fluid is determined to be used, measuring the activity of the drilling fluid to be used by using a hygrometer, determining the chemical potential difference between the drilling fluid and the formation fluid, determining the column pressure of the drilling fluid by using the chemical potential difference and the formation pore pressure according to the total potential energy balance principle, and determining the density of the drilling fluid according to the column pressure of the drilling fluid and the well depth;
if the drilling fluid density is determined, determining that the difference value between the drilling fluid column pressure and the formation pressure is an under-pressure value, obtaining a chemical potential difference by using the under-pressure value according to the total potential energy balance principle, and determining the drilling fluid activity according to the chemical potential difference and the formation water activity;
and (seventhly) adjusting the density or activity of the drilling fluid according to the determination result to keep the well wall stable.
The specific method in the step (one) is as follows:
(a) weighing several weight pieces of (W)I) The shale sample of (a);
(b) the shale samples were placed in an oven at 200 ° F for 24 hours and the weight (W) of each dry shale sample was measuredd）；
(c) The original water content of each shale sample is then:
（1）
(d) placing the dried shale samples in dryers with different activities;
(e) the weight of each sample was measured daily until the weight was not increasing, and the weight was recorded；
(f) Drawing an isothermal adsorption curve according to the adsorption capacity of the shale and the humidity of a dryer for placing the shale;
(g) determination of original formation water activity a using original formation water cutshale。
The servo control injection pump (1) in the film efficiency testing experimental device in the step (four) penetrates through the lower end of the constant temperature box (7) through the first high-pressure pipeline (2) to be connected with the lower end of the core holder (8), and the first high-pressure pipeline (2) is provided with the first valve (3) and the first pressure sensor (5); the servo control injection pump (1) is used for providing pressure for drilling fluid at the lower end of the rock core and providing circulating pressure for drilling fluid at the upper end of the rock core; the first valve (3) is used for controlling the inlet and outlet of drilling fluid at the lower end of the rock core holder (8); the first pressure sensor (5) is used for indicating and recording the drilling fluid pressure at the lower end of the core holder (8); a second valve (4) is externally connected between the first valve (3) and the first pressure sensor (5), and the second valve (4) is used for emptying or adjusting the pressure of drilling fluid on the lower end face of the core holder (8); the constant temperature box (7) is used for providing and maintaining the temperature required by the core holder (8) in the membrane efficiency test.
The experimental device comprises a servo control injection pump (1), a constant temperature box (7), a rock core holder (8), a computer data acquisition system (19), a back pressure regulator (21) and a liquid storage tank (28), wherein the rock core holder (8) is arranged in the constant temperature box (7), the servo control injection pump (1) is used for providing pressure for drilling fluid at the lower end of a rock core and providing circulating pressure for drilling fluid at the upper end of the rock core, and the back pressure regulator (21) is used for keeping the flowing pressure of the drilling fluid at the upper end of the rock core holder (8) constant; the computer data acquisition system (19) is used for acquiring and recording the pressure and the temperature in the constant temperature box (7) in real time; the core holder (8) comprises a core holder upper end cover (29), a core holder lower end cover (30), epoxy resin (9) and a sealing ring (31), the core (10) is clamped between the core holder upper end cover (29) and the core holder lower end cover (30), and the periphery of the core is wrapped by the epoxy resin (9) to form a regular sample.
The servo control injection pump (1) is connected with one end of a second high-pressure pipeline (11), the other end of the second high-pressure pipeline (11) penetrates through the upper end of the thermostat (7) to be connected with an inlet at the upper end of the core holder (8), a third valve (12) and a second pressure sensor (13) are arranged on the second high-pressure pipeline (11), the third valve (12) is used for controlling the inflow of drilling fluid at the upper end of the core holder (8), and the second pressure sensor (13) is used for indicating and recording the pressure of the drilling fluid at an inlet at the upper end of the core holder (8);
one end of a third high-pressure pipeline (15) is connected with a back pressure regulator (21), the other end of the third high-pressure pipeline penetrates through the upper end of the constant temperature box (7) to be connected with an outlet at the upper end of the rock core holder (8), and a fourth valve (20) and a third pressure sensor (16) are arranged on the third high-pressure pipeline (15); the fourth valve (20) is used for controlling the outflow of drilling fluid at the upper end of the core holder (8), the third pressure sensor (16) is used for indicating and recording the pressure of the drilling fluid at the outlet at the upper end of the core holder (8), the back pressure regulator (21) is used for keeping the flowing pressure of the drilling fluid at the upper end of the core holder (8) constant, the fifth valve (23) is connected between the fourth valve (20) and the back pressure regulator (21) through the fourth high-pressure pipeline (22), and the fifth valve (23) is used for emptying and replacing the circulating drilling fluid at the upper end face of the core holder (8);
one end of a fifth high-pressure pipeline (27) is connected with the back pressure regulator (21), the other end of the fifth high-pressure pipeline is connected with the upper end of the liquid storage tank (28), and a fourth pressure sensor (25) and a sixth valve (26) are arranged on the fifth high-pressure pipeline (27); the fourth pressure sensor (25) is used for indicating and recording the pressure of the drilling fluid at the outlet of the back pressure regulator (21), the sixth valve (26) is used for controlling the outflow of the drilling fluid at the outlet of the back pressure regulator (21), and the liquid storage tank (28) is used for collecting the drilling fluid which flows out circularly;
the computer data acquisition system (19) is connected with the first pressure sensor (5), the second pressure sensor (13), the third pressure sensor (16), the constant temperature box (7) and the fourth pressure sensor (25) through the first data acquisition line (6), the second data acquisition line (14), the third data acquisition line (17), the fourth data acquisition line (18) and the fifth data acquisition line (24), and the computer data acquisition system (19) is used for acquiring and recording the pressure of the first pressure sensor (5), the second pressure sensor (13), the third pressure sensor (16) and the fourth pressure sensor (25) and the temperature in the constant temperature box (7) in real time.
The core holder (8) comprises a core holder upper end cover (29), a core holder lower end cover (30), epoxy resin (9) and a sealing ring (31), wherein a core (10) is clamped between the core holder upper end cover (29) and the core holder lower end cover (30), the epoxy resin (9) wraps the periphery of the core to form a regular sample, and the core is fixed while drilling fluid is prevented from leaking out from the side; the bottom surface of an upper end cover (29) of the core holder, which is in contact with the core, and the top surface of a lower end cover (30) of the core holder are respectively provided with a sealing ring (31), and the sealing rings (31) are used for sealing the core and preventing the liquid at the top end and the bottom end from being communicated;
grooves are respectively formed in the lower end face of the upper end cover (29) of the core holder and the upper end face of the lower end cover (30) of the core holder, so that drilling fluid can flow conveniently; the second high-pressure pipeline (11) and the third high-pressure pipeline (15) are respectively connected with an upper end cover (29) of the core holder, and the second high-pressure pipeline (2) is connected with a lower end cover (30) of the core holder.
Compared with the prior art, the invention has the following beneficial effects:
(1) the effect of chemical potential is fully considered, the density of the drilling fluid when the total potential energy of the stratum is kept balanced is accurately given, the filtrate of the drilling fluid is effectively prevented from invading the stratum, the stability of the well wall is improved, and the application and popularization of the underbalanced drilling technology are enhanced;
(2) when the underpressure value is determined, the stability of the well wall can be kept by adjusting the activity of the drilling fluid, so that the mechanical drilling speed is improved, the service life of a drill bit is prolonged, the drilling efficiency is improved, and the rapid and safe drilling is guaranteed;
(3) the method provided by the invention is simple and convenient, strong in operability, good in application effect, wide in popularization prospect and strong in guiding significance for field drilling construction;
(4) the film efficiency tester utilizes the epoxy resin to seal the rock core, overcomes the defect that the irregular rock core cannot be measured or the rock core falls off in the previous research, solves the difficulty that the test rock core is difficult to obtain, realizes that the formation film efficiency at different depths can be tested by using the underground falling off, improves the application range of the underbalanced drilling technology, and is more instructive to the field application;
(5) this membrane efficiency tester has increased the thermostated container, has realized opening up membrane efficiency test experiment under the high temperature condition, has overcome the drawback that temperature fluctuation produces the error to the test result.
Drawings
FIG. 1 is a flow chart of a novel under-balanced well wall stability calculation method provided by the invention;
FIG. 2 is a schematic diagram of an experimental apparatus for testing the efficiency of a shale membrane according to the present invention;
FIG. 3 is a schematic view of a core holder in an incubator;
FIG. 4 is a cross-sectional view of the bottom end face of the upper end cover of the core holder;
FIG. 5 is a cross-sectional view of the upper end of the lower end cap of the core holder;
FIG. 6 is a graph of isothermal adsorption;
FIG. 7 is a pressure profile of a overburden
FIG. 8 is a plot of normal pressure trend of the formation;
in the upper diagram: the device comprises a servo control injection pump (1), a first high-pressure pipeline (2), a first valve (3), a second valve (4), a first pressure sensor (5), a first data acquisition line (6), a thermostat (7), a rock core holder (8), epoxy resin (9), a rock core (10), a second high-pressure pipeline (11), a third valve (12), a second pressure sensor (13), a second data acquisition line (14), a third high-pressure pipeline (15), a third pressure sensor (16), a third data acquisition line (17), a fourth data acquisition line (18), a computer data acquisition system (19), a fourth valve (20), a back pressure regulator (21), a fourth high-pressure pipeline (22), a fifth valve (23), a fifth data acquisition line (24), a fourth pressure sensor (25), a sixth valve (26), a fifth high-pressure pipeline (27), The device comprises a liquid storage tank (28), a core holder upper end cover (29), a core holder lower end cover (30) and a sealing ring (31).
Detailed Description
The invention provides a novel under-balanced drilling well wall stabilizing technology which is described in the following by combining the attached drawings and embodiments.
In order to achieve the purpose, the invention adopts the following technical scheme:
the method comprises the following steps of firstly, collecting water activity of a shale formation by using an isothermal adsorption test, and specifically comprises the following steps:
(1) weighing several weight pieces of (W)I) The shale sample of (a);
(2) the shale samples were placed in an oven at 200 ° F for 24 hours and the weight (W) of each dry shale sample was measuredd）；
(3) The original water content of each shale sample is then:
（1）
(4) placing the dried shale samples in dryers with different activities;
(5) the weight of each sample was measured daily until the weight was not increasing, and the weight was recorded。
(6) And drawing an isothermal adsorption curve according to the adsorption capacity of the shale and the humidity of a dryer for placing the shale.
(7) Determination of original formation activity a using original formation water cutshaleSpecifically, as shown in the above figure, the water activity of the virgin formation is determined to be 0.915 according to the water content of the virgin formation shale.
Secondly, determining the pore pressure of the stratum to be drilled according to the adjacent well logging data and the formation pressure test data;
(1) computation of overburden pressure using formation density log datas v 。
（2）
In the formula:is covered with a pressure gradient of g/cm at a certain depth3；s v Is overburden pressure, MPa;is the average density of the upper part of the stratum without logging information, g/cm3；The thickness of the upper part of the stratum without logging information is m;is density scatter data of a certain depth, g/cm3；Is a depth interval between which the depth of the image is measured,；His the well depth, m. And calculating according to the log data to obtain the overburden pressure profile of the lower map.
(2) And establishing a normal compaction trend line of the stratum in the area by utilizing the time difference logging data of the adjacent 3-5 well acoustic waves, and determining coefficients A and B in the following formula.
（3）
In the formulaIs the time difference of the formation acoustic wave at the depth h, μ s/m; h is vertical depth, m; a and B are normal trend line coefficients. The pressure trend lines established are shown in the following graph.
(3) And (4) obtaining a formation index c according to the pressure of the overlying strata layer of the formation and the actual oil test data by the following formula.
（4）
Wherein,s v is overburden pressure, MPa;P n normal formation pressure, MPa;P p actual formation pressure, MPa; dt n To predict the acoustic time difference on the normal trend line of depth, μ s/m; dt s In order to predict the actual acoustic wave time difference of the deep stratum, the Mus/m;
(4) the formation pore pressure is calculated using the Eton formula:
（5）
wherein,cis the index of the region,P p is the predicted actual formation pressure, MPa; .
And thirdly, the formation temperature can be determined according to formation temperature data of logging while drilling, and can also be calculated according to the geothermal gradient of the region by the following formula.
In the formulaIs the absolute temperature gradient of the formation;is the ground average temperature, deg.C;is the regional ground temperature gradient, DEG C/100 m; h is the formation depth, m.
Measuring the formation membrane efficiency by using a membrane efficiency test experimental device, wherein the specific method comprises the following steps;
as shown in fig. 2, the membrane efficiency test experimental apparatus includes: the device comprises a servo control injection pump 1, an incubator 7, a rock core holder 8, a computer data acquisition system 19, a back pressure regulator 21, a liquid storage tank 28 and the rock core holder 8, wherein the servo control injection pump, the incubator 7, the rock core holder 8, the computer data acquisition system and the liquid storage tank 28 are arranged in the incubator 7.
The servo control injection pump 1 penetrates through the lower end of the constant temperature box 7 through a first high-pressure pipeline 2 and is connected with the lower end of the rock core holder 8, and a first valve 3 and a first pressure sensor 5 are arranged on the first high-pressure pipeline 2; the servo control injection pump 1 is used for providing pressure for drilling fluid at the lower end of the rock core and providing circulating pressure for drilling fluid at the upper end of the rock core; the first valve 3 is used for controlling the inlet and outlet of drilling fluid at the lower end of the rock core holder 8; the first pressure sensor 5 is used for indicating and recording the drilling fluid pressure at the lower end of the core holder 8; a second valve 4 is externally connected between the first valve 3 and the first pressure sensor 5, and the second valve 4 is used for emptying or adjusting the drilling fluid pressure on the lower end face of the core holder 8; the oven 7 is used to supply and maintain the temperature required by the core holder 8 for the membrane efficiency test.
One end of a second high-pressure pipeline 11 is connected with the servo control injection pump 1, the other end of the second high-pressure pipeline penetrates through the upper end of the thermostat 7 and is connected with an inlet at the upper end of the core holder 8, a third valve 12 and a second pressure sensor 13 are arranged on the second high-pressure pipeline 11, the third valve 12 is used for controlling the inflow of drilling fluid at the upper end of the core holder 8, and the second pressure sensor 13 is used for indicating and recording the drilling fluid pressure at the inlet at the upper end of the core holder 8.
One end of a third high-pressure pipeline 15 is connected with a back pressure regulator 21, the other end of the third high-pressure pipeline passes through the upper end of the constant temperature box 7 and is connected with an upper end outlet of the rock core holder 8, and a fourth valve 20 and a third pressure sensor 16 are arranged on the third high-pressure pipeline 15; the fourth valve 20 is used for controlling the outflow of the drilling fluid at the upper end of the core holder 8, the third pressure sensor 16 is used for indicating and recording the drilling fluid pressure at the outlet of the upper end of the core holder 8, and the back pressure regulator 21 is used for keeping the flowing pressure of the drilling fluid at the upper end of the core holder 8 constant. A fourth high-pressure line 22 connects a fifth valve 23 between the fourth valve 20 and the back pressure regulator 21, the fifth valve 23 being used for emptying and displacing the circulating drilling fluid from the upper side of the core holder 8.
One end of a fifth high-pressure pipeline 27 is connected with the back pressure regulator 21, the other end of the fifth high-pressure pipeline 27 is connected with the upper end of the liquid storage tank 28, and a fourth pressure sensor 25 and a sixth valve 26 are arranged on the fifth high-pressure pipeline 27; a fourth pressure sensor 25 is used to indicate and record the pressure of the drilling fluid at the outlet of the back pressure regulator 21, a sixth valve 26 is used to control the outflow of drilling fluid at the outlet of the back pressure regulator 21, and a reservoir 28 is used to collect the circulating outflow of drilling fluid.
The computer data acquisition system 19 is respectively connected with the first pressure sensor 5, the second pressure sensor 13, the third pressure sensor 16, the incubator 7 and the fourth pressure sensor 25 through the first data acquisition line 6, the second data acquisition line 14, the third data acquisition line 17, the fourth data acquisition line 18 and the fifth data acquisition line 24, and the computer data acquisition system 19 is used for acquiring and recording the pressures of the first pressure sensor 5, the second pressure sensor 13, the third pressure sensor 16 and the fourth pressure sensor 25 and the temperature in the incubator 7 in real time.
As shown in fig. 3, the core holder 8 includes: the core holder comprises a core holder upper end cover 29, a core holder lower end cover 30, epoxy resin 9 and a sealing ring 31, wherein a core 10 is clamped between the core holder upper end cover 29 and the core holder lower end cover 30, the epoxy resin 9 wraps the periphery of the core to form a regular sample, and the core is fixed while drilling fluid is prevented from leaking out from the side; and the bottom surface of the upper end cover 29 of the core holder, which is in contact with the core, and the top surface of the lower end cover 30 of the core holder are respectively provided with a sealing ring 31, and the sealing rings 31 are used for sealing the core and preventing the liquid at the top end and the bottom end from being communicated. As shown in fig. 3 and 4, grooves are respectively formed on the lower end surface of the upper end cover 29 of the core holder and the upper end surface of the lower end cover 30 of the core holder, so that drilling fluid can flow conveniently; the second high-pressure pipeline 11 and the third high-pressure pipeline 15 are respectively connected with an upper end cover 29 of the core holder, and the second high-pressure pipeline 2 is connected with a lower end cover 30 of the core holder.
As shown in fig. 4, the cross section of the bottom end surface of the upper end cover 29 of the core holder is provided with a groove, so that the drilling fluid can flow on the inlet end surface of the core conveniently;
as shown in fig. 5, the cross section of the upper end surface of the lower end cover 30 of the core holder is provided with a groove, so that the drilling fluid can flow on the end surface of the outlet of the core conveniently;
the method for simulating the membrane efficiency test experiment utilizes the experimental device, and comprises the following specific experimental steps:
(1) preparing drilling fluid, formation fluid and a rock core to be tested;
(2) placing a rock core 10 to be tested in epoxy resin 9 to prepare a standard sample required by the test, installing the standard sample to be tested on a rock core holder 8, placing the standard sample in a constant temperature box 7, and adjusting the temperature in the constant temperature box 7 to be a set temperature;
(3) core saturation stage
Filling formation fluid in a servo control injection pump 1; opening the first valve 3, keeping the other valves in a closed state, gradually injecting formation fluid into the bottom end of the rock core holder 8 by using the servo control injection pump 1 and increasing pressure until the pressure value displayed by the first pressure sensor 5 reaches a set value, and closing the first valve 3 after the pressure value is stabilized;
opening the third valve 12, the fourth valve 20, the fifth valve 23, the first valve 3, the second valve 4 and the sixth valve 26; and gradually injecting formation fluid into the top end of the core holder 8 by using the servo control injection pump 1, enabling the top end of the core holder 8 of the formation fluid to circularly flow, closing the fifth valve 23, adjusting the back pressure regulator 21, opening the sixth valve 26 when the formation fluid flows out from the outlet of the fifth valve 23, and controlling the circulating flow pressure at the top end of the core holder 8 to be greater than the bottom pressure by 0.5MPa by using the servo control injection pump 1 and the back pressure regulator 21 and keeping the pressure constant.
Thirdly, acquiring and recording pressure data of the first pressure sensor 5, the second pressure sensor 13, the third pressure sensor 16 and the fourth pressure sensor 25 by using the computer data acquisition system 19, observing the second pressure sensor 13 and the third pressure sensor 16, if a large difference occurs, indicating that a pore channel is blocked, and the experiment fails, and if the pressures are equal, the experiment is normal; at this time, the pressure data of the first pressure sensor 5 is observed, and when the pressures of the first pressure sensor 5 and the third pressure sensor 16 are equal, the core saturation stage is completed.
(4) Membrane efficiency testing stage
Firstly, after a rock core saturation stage is completed, replacing fluid in a servo control injection pump 1 with designed drilling fluid; and the top of the core holder 8 is gradually filled until the circulated out drilling fluid flows into the reservoir 28.
② the actual expansion pressure is the maximum pressure difference recorded by the third pressure sensor 16 and the first pressure sensor 5s Measuring。
(5) After the test experiment is finished, opening the second valve 4, the fourth valve 20, the fifth valve 23 and the sixth valve 26, and closing the first valve 3 and the third valve 12; and releasing the pressure, discharging the fluid, and then taking out the core, thereby finishing the experiment.
(6) And calculating the membrane efficiency.
Firstly, calculating theoretical osmotic pressure according to the following formula;
is the gas constant, 8.314J/(mol K),is the absolute temperature, K,is the partial molar volume L/mol of water,is the activity of the fluid at the bottom end,is the top circulating fluid activity.
Reuse formula 7 to calculate Membrane efficiency
Measuring the activity of the drilling fluid to be used by using a hygrometer if certain drilling fluid is determined to be used, determining the chemical potential difference between the drilling fluid and the formation fluid, determining the fluid column pressure of the drilling fluid by using the chemical potential difference and the formation pore pressure according to the total potential energy balance principle, and determining the density of the drilling fluid according to the fluid column pressure of the drilling fluid and the well depth;
and sixthly, if the undervoltage value (the difference value between the pressure of the drilling fluid column and the pressure of the stratum) is determined, determining the chemical potential difference by using the undervoltage value according to the total potential energy balance principle, and then determining the drilling fluid activity according to the chemical potential difference and the stratum water activity.
And seventhly, adjusting the density or activity of the drilling fluid according to the determination result to keep the well wall stable.
Wherein, the total potential energy formula is as follows:
when the drilling fluid activity is known, the calculation method is as follows:
wherein, the chemical potential difference calculation formula between the drilling fluid and the formation fluid is as follows:
in the formula,is the chemical potential of pure water,is the constant of the gas and is,is the temperature of the liquid to be measured in absolute terms,is the partial molar volume of water,is the activity of the drilling filtrate and is,is the water activity of the shale formation.
The pressure of the borehole wall fluid column when the total potential energy is balanced can be obtained by driving the formula (9) into the formula (8):
in the formula,in order to determine the pore pressure of the formation water,in order to be the pressure of the borehole wall fluid column,is the membrane efficiency.
Wherein, the drilling fluid equivalent density calculation formula is as follows:
in the formula,h is the vertical depth, which is the drilling fluid equivalent density.
Secondly, knowing the under-voltage value, the calculation method is as follows:
bringing formula (9) into formula (8) to obtain
In the formula,is an under-voltage value.
The drilling fluid activity calculation formula is as follows:
Claims (7)
1. A well wall stabilizing method suitable for underbalanced drilling is characterized by comprising the following steps:
collecting and determining the formation water activity of the shale by using an isothermal adsorption test;
determining the pore pressure of the stratum to be drilled according to the adjacent well logging data and the formation pressure test data;
determining the formation temperature according to formation temperature data of logging while drilling, or calculating the formation temperature according to the geothermal gradient of the region;
measuring the formation membrane efficiency by using a membrane efficiency test experimental device; the membrane efficiency testing experimental device comprises a servo control injection pump (1), a constant temperature box (7), a rock core holder (8), a computer data acquisition system (19), a back pressure regulator (21) and a liquid storage box (28), wherein the rock core holder (8) is arranged in the constant temperature box (7), the servo control injection pump (1) is used for providing pressure for drilling fluid at the lower end of a rock core and providing circulating pressure for drilling fluid at the upper end of the rock core, and the back pressure regulator (21) is used for keeping the flowing pressure of the drilling fluid at the upper end of the rock core holder (8) constant; the computer data acquisition system (19) is used for acquiring and recording the pressure and the temperature in the constant temperature box (7) in real time; the core holder (8) comprises a core holder upper end cover (29), a core holder lower end cover (30), epoxy resin (9) and a sealing ring (31), the core (10) is clamped between the core holder upper end cover (29) and the core holder lower end cover (30), and the epoxy resin (9) wraps the periphery of the core to form a regular sample;
if certain drilling fluid is determined to be used, measuring the activity of the drilling fluid to be used by using a hygrometer, determining the chemical potential difference between the drilling fluid and the formation fluid, determining the column pressure of the drilling fluid by using the chemical potential difference and the formation pore pressure according to the total potential energy balance principle, and determining the density of the drilling fluid according to the column pressure of the drilling fluid and the well depth;
if the drilling fluid density is determined, determining that the difference value between the drilling fluid column pressure and the formation pressure is an under-pressure value, obtaining a chemical potential difference by using the under-pressure value according to the total potential energy balance principle, and determining the drilling fluid activity according to the chemical potential difference and the formation water activity;
and (seventhly) adjusting the density or activity of the drilling fluid according to the determination result to keep the well wall stable.
2. The method of claim 1 for borehole wall stabilization for underbalanced drilling, wherein: the specific method in the step (one) is as follows:
(a) weighing several weight pieces of (W)i) The shale sample of (a);
(b) book pageThe rock samples were placed in an oven at 200 ° F for 24 hours, and then the weight (W) of each dry shale sample was measuredd）；
(c) The original water content of each shale sample is then:
(d) placing the dried shale samples in dryers with different activities;
(e) the weight of each sample was measured daily until the weight did not increase, and the weight was recorded；
(f) Drawing an isothermal adsorption curve according to the adsorption capacity of the shale and the humidity of a dryer for placing the shale;
(g) determination of original formation water activity a using original water cutshale。
3. The method of claim 1 for borehole wall stabilization for underbalanced drilling, wherein: a servo control injection pump (1) in the membrane efficiency test experimental device in the step (IV) penetrates through the lower end of the constant temperature box (7) through a first high-pressure pipeline (2) to be connected with the lower end of the core holder (8), and a first valve (3) and a first pressure sensor (5) are arranged on the first high-pressure pipeline (2); the servo control injection pump (1) is used for providing pressure for drilling fluid at the lower end of the rock core and providing circulating pressure for drilling fluid at the upper end of the rock core; the first valve (3) is used for controlling the inlet and outlet of drilling fluid at the lower end of the rock core holder (8); the first pressure sensor (5) is used for indicating and recording the drilling fluid pressure at the lower end of the core holder (8); a second valve (4) is externally connected between the first valve (3) and the first pressure sensor (5), and the second valve (4) is used for emptying or adjusting the drilling fluid pressure on the lower end face of the rock core holder (8); the constant temperature box (7) is used for providing and maintaining the temperature required by the core holder (8) in the film efficiency test.
4. A membrane efficiency testing experimental device applied to the borehole wall stabilizing method suitable for underbalanced drilling according to any one of claims 1 to 3, which is characterized in that: the core holder is characterized by comprising a servo control injection pump (1), a constant temperature box (7), a core holder (8), a computer data acquisition system (19), a back pressure regulator (21) and a liquid storage box (28), wherein the core holder (8) is arranged in the constant temperature box (7), the servo control injection pump (1) is used for providing pressure for drilling fluid at the lower end of a core and providing circulating pressure for drilling fluid at the upper end of the core, and the back pressure regulator (21) is used for keeping the flowing pressure of the drilling fluid at the upper end of the core holder (8) constant; the computer data acquisition system (19) is used for acquiring and recording the pressure and the temperature in the constant temperature box (7) in real time; the core holder (8) comprises a core holder upper end cover (29), a core holder lower end cover (30), epoxy resin (9) and a sealing ring (31), the core (10) is clamped between the core holder upper end cover (29) and the core holder lower end cover (30), and the periphery of the core is wrapped by the epoxy resin (9) to form a regular sample.
5. The experimental apparatus for testing membrane efficiency in the well wall stabilizing method for underbalanced drilling as claimed in claim 4, wherein: the servo control injection pump (1) is connected with one end of a second high-pressure pipeline (11), the other end of the second high-pressure pipeline (11) penetrates through the upper end of the thermostat (7) to be connected with an upper end inlet of the core holder (8), a third valve (12) and a second pressure sensor (13) are arranged on the second high-pressure pipeline (11), the third valve (12) is used for controlling the inflow of drilling fluid at the upper end of the core holder (8), and the second pressure sensor (13) is used for indicating and recording the pressure of the drilling fluid at the upper end inlet of the core holder (8);
one end of a third high-pressure pipeline (15) is connected with a back pressure regulator (21), the other end of the third high-pressure pipeline penetrates through the upper end of the constant temperature box (7) to be connected with an outlet at the upper end of the rock core holder (8), and a fourth valve (20) and a third pressure sensor (16) are arranged on the third high-pressure pipeline (15); the fourth valve (20) is used for controlling the outflow of drilling fluid at the upper end of the core holder (8), the third pressure sensor (16) is used for indicating and recording the pressure of the drilling fluid at an outlet at the upper end of the core holder (8), the back pressure regulator (21) is used for keeping the flowing pressure of the drilling fluid at the upper end of the core holder (8) constant, the fifth valve (23) is connected between the fourth valve (20) and the back pressure regulator (21) through a fourth high-pressure pipeline (22), and the fifth valve (23) is used for emptying and replacing the circulating drilling fluid at the upper end face of the core holder (8);
one end of a fifth high-pressure pipeline (27) is connected with the back pressure regulator (21), the other end of the fifth high-pressure pipeline is connected with the upper end of the liquid storage tank (28), and a fourth pressure sensor (25) and a sixth valve (26) are arranged on the fifth high-pressure pipeline (27); the fourth pressure sensor (25) is used for indicating and recording the pressure of the drilling fluid at the outlet of the back pressure regulator (21), the sixth valve (26) is used for controlling the outflow of the drilling fluid at the outlet of the back pressure regulator (21), and the liquid storage tank (28) is used for collecting the drilling fluid which flows out circularly;
the computer data acquisition system (19) is connected with the first pressure sensor (5), the second pressure sensor (13), the third pressure sensor (16), the constant temperature box (7) and the fourth pressure sensor (25) through the first data acquisition line (6), the second data acquisition line (14), the third data acquisition line (17), the fourth data acquisition line (18) and the fifth data acquisition line (24), and the computer data acquisition system (19) is used for acquiring and recording the pressure of the first pressure sensor (5), the second pressure sensor (13), the third pressure sensor (16) and the fourth pressure sensor (25) and the temperature in the constant temperature box (7) in real time.
6. The experimental apparatus for testing membrane efficiency in the well wall stabilizing method for underbalanced drilling as claimed in claim 4, wherein: the core holder (8) comprises a core holder upper end cover (29), a core holder lower end cover (30), epoxy resin (9) and a sealing ring (31), the core (10) is clamped between the core holder upper end cover (29) and the core holder lower end cover (30), the epoxy resin (9) wraps the periphery of the core to form a regular sample, and the core is fixed while drilling fluid is prevented from leaking out from the side; and the bottom surface of the upper end cover (29) of the core holder, which is contacted with the core, and the top surface of the lower end cover (30) of the core holder are respectively provided with a sealing ring (31), and the sealing rings (31) are used for sealing the core and preventing the liquid at the top end and the bottom end from being communicated.
7. The experimental apparatus for testing membrane efficiency in the well wall stabilizing method for underbalanced drilling as claimed in claim 6, wherein: grooves are respectively formed in the lower end face of the upper end cover (29) of the core holder and the upper end face of the lower end cover (30) of the core holder, so that drilling fluid can flow conveniently; the second high-pressure pipeline (11) and the third high-pressure pipeline (15) are respectively connected with an upper end cover (29) of the core holder, and the second high-pressure pipeline (2) is connected with a lower end cover (30) of the core holder.
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| CA3003510C (en) * | 2015-10-29 | 2020-10-13 | Nexen Energy Ulc | Emulsion composition sensor |
| CN105298385B (en) * | 2015-11-05 | 2017-07-14 | 中石化石油工程技术服务有限公司 | A kind of boring method for reinforcing mud shale with boring |
| CN105626056B (en) * | 2015-12-22 | 2019-01-18 | 中国石油天然气集团公司 | A kind of method and apparatus of determining target area three-dimensional formation pore pressure |
| CN105781541A (en) * | 2016-03-17 | 2016-07-20 | 成都创源油气技术开发有限公司 | Logging evaluation method for shale borehole stability |
| CN110748339B (en) * | 2018-07-24 | 2022-12-23 | 中石化石油工程技术服务有限公司 | Method for stabilizing shale formation by adjusting drilling fluid activity |
| CN110761784B (en) * | 2018-07-26 | 2023-01-10 | 中国石油天然气股份有限公司 | Method for determining chemical window of well bore working fluid |
| CN108661626B (en) * | 2018-08-02 | 2023-11-21 | 西南石油大学 | High-temperature high-pressure well wall water invasion simulation experiment device |
| CN109236285B (en) * | 2018-09-30 | 2022-02-18 | 西南石油大学 | Single-well undisturbed stratum mechanical profile calculation method and system |
| CN111855484B (en) * | 2020-07-30 | 2022-05-20 | 西南石油大学 | Method for evaluating drilling fluid stable shale stratum well wall capability based on acoustoelectric response |
| US11828169B2 (en) * | 2020-11-12 | 2023-11-28 | Saudi Arabian Oil Company | Method of determining in-situ pore pressure in chemically active formations |
| CN113533655B (en) * | 2021-07-23 | 2022-09-16 | 中国石油大学(北京) | Device for simulating stratum respiration effect and control method |
| CN114718550A (en) * | 2022-04-07 | 2022-07-08 | 中国石油大学(华东) | Experimental device and method for evaluating well wall damage |
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| US8466094B2 (en) * | 2009-05-13 | 2013-06-18 | Clearwater International, Llc | Aggregating compositions, modified particulate metal-oxides, modified formation surfaces, and methods for making and using same |
| CN102182444B (en) * | 2011-04-01 | 2014-07-02 | 中国石油集团川庆钻探工程有限公司 | Under-balanced drilling adaptability evaluation method |
| CN103868841B (en) * | 2014-03-28 | 2016-03-02 | 海安县石油科研仪器有限公司 | Measure the experimental provision of extremely low mud shale permeability and membrane efficiency |
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