CN108316915A - A kind of method that the optimal dosage of diversion agent is temporarily blocked up in determining oil/gas well compact reservoir - Google Patents
A kind of method that the optimal dosage of diversion agent is temporarily blocked up in determining oil/gas well compact reservoir Download PDFInfo
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- CN108316915A CN108316915A CN201711386760.0A CN201711386760A CN108316915A CN 108316915 A CN108316915 A CN 108316915A CN 201711386760 A CN201711386760 A CN 201711386760A CN 108316915 A CN108316915 A CN 108316915A
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- 238000000034 method Methods 0.000 title claims abstract description 16
- 239000000835 fiber Substances 0.000 claims abstract description 52
- 239000012065 filter cake Substances 0.000 claims abstract description 26
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 13
- 239000007788 liquid Substances 0.000 claims abstract description 10
- 230000003071 parasitic effect Effects 0.000 claims abstract description 10
- 239000011435 rock Substances 0.000 claims abstract description 10
- 230000006698 induction Effects 0.000 claims abstract description 6
- 230000005540 biological transmission Effects 0.000 claims abstract description 3
- 239000012530 fluid Substances 0.000 claims description 13
- 238000002347 injection Methods 0.000 claims description 9
- 239000007924 injection Substances 0.000 claims description 9
- 241000209094 Oryza Species 0.000 claims description 6
- 235000007164 Oryza sativa Nutrition 0.000 claims description 6
- 230000035699 permeability Effects 0.000 claims description 6
- 235000009566 rice Nutrition 0.000 claims description 6
- 238000005553 drilling Methods 0.000 claims description 5
- 230000015572 biosynthetic process Effects 0.000 claims description 4
- 230000003068 static effect Effects 0.000 claims description 4
- 239000003245 coal Substances 0.000 claims description 3
- 238000013459 approach Methods 0.000 claims description 2
- 230000000903 blocking effect Effects 0.000 claims description 2
- 239000012263 liquid product Substances 0.000 claims 1
- 238000013461 design Methods 0.000 abstract description 4
- 238000010008 shearing Methods 0.000 abstract description 3
- 239000002253 acid Substances 0.000 description 9
- 230000000694 effects Effects 0.000 description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 3
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 2
- 238000004891 communication Methods 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 230000035515 penetration Effects 0.000 description 2
- ORILYTVJVMAKLC-UHFFFAOYSA-N Adamantane Natural products C1C(C2)CC3CC1CC2C3 ORILYTVJVMAKLC-UHFFFAOYSA-N 0.000 description 1
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 241000361919 Metaphire sieboldi Species 0.000 description 1
- 230000003321 amplification Effects 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 230000002708 enhancing effect Effects 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 230000001939 inductive effect Effects 0.000 description 1
- 238000009533 lab test Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000003199 nucleic acid amplification method Methods 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 239000004575 stone Substances 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 238000012360 testing method Methods 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
-
- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
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- Mining & Mineral Resources (AREA)
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- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Geophysics And Detection Of Objects (AREA)
- Force Measurement Appropriate To Specific Purposes (AREA)
Abstract
A kind of method that the optimal dosage of diversion agent is temporarily blocked up in determining oil/gas well compact reservoir, including step：(1) tangential stress on the borehole wall is calculated；(2) tangential stress that flow-induced is injected at the borehole wall is calculated；(3) stress of man-made fracture induction at the borehole wall is calculated；(4) it is stress under polar coordinates by stress transmission under rectangular co-ordinate, obtains the tangential stress of man-made fracture induction；(5) the tangential stress field formula simultaneous by first three in walking obtains the tangential stress distribution around the borehole wall after the first pressure break；(6) according to rock elasticity fracture criteria, fiber filter cake parasitic pressure drop value has to be larger than the minimum of borehole wall tangential stress after first time pressure break plus the sum of shearing stress at first time pressure-break, determines fiber filter cake parasitic pressure drop optimal value；(7) corresponding optimal fiber filter cake length is calculated according to Darcy formula；(8) optimal volume of the temporary stall of fiber to liquid is calculated.Temporarily stifled diversion agent dosage can effectively be optimized, meet the needs of compact reservoir turnaround fracture design.
Description
Technical field
The invention belongs to oil and gas exploration technology fields, and in particular to temporarily be blocked up in a kind of determining oil/gas well compact reservoir
The optimal dosage method of diversion agent.
Background technology
When reservoir ground stress deviation is larger, compressibility is poor, it is difficult to form complex fracture in hydraulic fracturing process, by temporary
It is the important means that enhancing seam net extends complexity to block up and force crack steering.In temporary stall into fracturing process, pass through temporary stall
Artificial add is introduced to agent to block, blocks the crack being previously formed and high seepage channel, for carrying out control turnaround fracture, is improved
The reconstruction scope and effect.Carbonate rock hydrocarbon reservoir is had been used at present turns to acid fracturing, tight gas reservoir turnaround fracture and shale gas repetition
The field applications such as pressure break.
Dashti et al. improves carbonate complex rock formation acidizing acidfracturing treatment using chemical diverter and biodegradable fiber
Effect, control acid liquid loss enter wider Reproducible ability, earthworm bore region and hypertonic region, are conducive to acid solution deep penetration, carry
High reservoir longitudinal direction use rate.Adam and Zhou et al. study RDF and turn to liquid system, by fiber for temporarily blocking up the crack pressed off,
Pressure in seam is promoted, man-made fracture is made to crack from new direction.Before and after laboratory experiment shows fiber injection, pressure maximum amplification can
Up to 30MPa, its good steering behaviour is shown.
Temporarily the dosage of stifled diversion agent is the key that temporary stall to FRACTURING DESIGN, relies primarily on field experience or simple meter at present
It calculates, there are no the methods that diversion agent dosage is temporarily blocked up in a set of effective optimization, it is difficult to meet compact reservoir turnaround fracture design scheme
Demand.
Invention content
In order to solve the above problem, the object of the present invention is to provide temporarily block up diversion agent most in a kind of determining oil/gas well compact reservoir
Excellent dosage method reaches reduction material cost, increases the purpose of turnaround fracture success rate.
In order to achieve the above objectives, a kind of method that the optimal dosage of diversion agent is temporarily blocked up in determining oil/gas well compact reservoir is provided,
This approach includes the following steps：
Step 1：Tangential stress after calculating drilling well on the borehole wall of oil/gas well, formula are as follows：
σθ0=-pw+(σH+σh)-2(σH-σh)cos(2θ) (1)
Wherein, pwFor shaft bottom fluid column static pressure, unit is megapascal；σHAnd σhIt is single for far field maximum, minimum horizontal principal stress
Position is：Megapascal；θ is polar angle, i.e., the angle in hole diameter direction and x-axis forward direction, unit are radian；
Step 2：At the borehole wall of oil/gas well, the tangential stress of injection flow-induced is calculated, formula is as follows：
σθ1=η (pw-p0) (2)
Wherein, pwFor shaft bottom fluid column static pressure, unit is megapascal；p0For original formation pressure, unit is megapascal；α is Biot coefficient of elasticity, and ν is Rock Poisson Ratio Using；
Step 3：At the borehole wall of oil/gas well, the stress difference for calculating man-made fracture induction is as follows：
△σy=ν (△ σx+△σz)(5)
In formula：
Wherein, rwFor wellbore radius, unit is rice；r1For polar diameter, the i.e. arithmetic square of wellbore radius and the high quadratic sum of dummy joint
Root, unit are rice；C is that dummy joint is high, and unit is rice；If θ1For negative value, then θ is used1+ π is replaced；P is net pressure in man-made fracture,
Unit is megapascal.
Step 4：By stress transmission under step 3 rectangular co-ordinate at the stress under polar coordinates, obtain at the oil/gas well borehole wall,
The tangential stress of man-made fracture induction, formula are as follows：
Step 5：By above formula (1), (2) and formula (8) phase simultaneous, you can obtain after the first pressure break around the oil/gas well borehole wall
Tangential stress distribution；
Step 6：According to rock elasticity fracture criteria, tangentially stress smallest point is opened and is split man-made fracture；Therefore, for
Crack after fiber must be added and opened from new direction and split, fiber filter cake parasitic pressure drop value is plus the sum of shearing stress at first time pressure-break
The minimum of borehole wall tangential stress after first time pressure break is had to be larger than, i.e.,
△pfiber+σθx≥σθ,min+T (9)
In formula, Δ pfiberIndicate fiber filter cake parasitic pressure drop value；Unit is megapascal；σθxIt indicates to cut at first time pressure-break
To stress；Unit is megapascal；σθ,minThe minimum of borehole wall tangential stress after expression first time pressure break；Unit is megapascal；T indicates rock
The tensile strength of stone, unit are megapascal；
So that it is determined that the optimal value of fiber filter cake parasitic pressure drop；
Step 7：Measure field fibre concentration is 2%, according to Darcy formula：Q=kA Δs P/ (μ L)=kwh Δs P/ (μ L),
It calculates discharge capacity and is less than 1.5m3Corresponding optimal fiber filter cake length when/min；
Wherein, k is fiber Permeability；L is optimal fiber filter cake length；Unit is m；μ is fracturing fluid viscosity；Unit
For：Pa·s；Q is the discharge capacity for injecting fiber fracturing liquid, and unit is：m3/min；W is slit width, unit m；H is that seam is high；Unit is
m；PKN or KGD (PKN can be passed through:Perkins-Kern-Nordgren；KGD:Khristianovic-Geertsma-de
Klerk takes initial) model or fracture software be calculated；Δ P is the fiber filter cake parasitic pressure drop obtained in the 6th step
Optimal value, unit are megapascal；
Step 8：By the optimal fiber filter cake length obtained in step 7, determines and calculate the temporary stall of fiber to liquid most
Excellent volume is 2 × optimal fiber filter cake length × high ÷ fibre concentrations of slit width × seam, and formula is as follows：
Vopt=2Lwh/n (10)
Wherein, n is that concentration, a concentration of quality volume fraction is added in fiber；L is fiber filter cake length；Unit is m；W is
Slit width, unit m；H is that seam is high, unit m.
Preferably, the compact reservoir includes shale gas, coal bed gas or the fine and close oil gas in hot dry rock, untraditional reservoir
Reservoir, the hyposmosis in conventional oil gas reservoir or super-low permeability reservoir.
Preferably, the oil/gas well includes straight well, horizontal well or the inclined shaft in above-mentioned compact reservoir.
Beneficial effects of the present invention：The present invention provides a kind of methods determining the temporarily optimal dosage of stifled diversion agent, not only fit
For untraditional reservoirs such as shale gas, coal bed gas, fine and close oil gas, the conventional gas and oil of hyposmosis and ultra-low penetration is applied also for
It hides；Meanwhile this method can be not only used for the temporary stall of straight well and construct to fracturing reform, can also be applied to the temporary stifled of horizontal well, inclined shaft etc.
Turnaround fracture rebuilding construction.This method can effectively optimize temporarily stifled diversion agent dosage, meet compact reservoir turnaround fracture design scheme
Demand.
Description of the drawings
Fig. 1 (a) is shear Stress Distribution curve at the borehole wall after drilling well；
Fig. 1 (b) is that injection fluid induces tangential stress distribution curve at the borehole wall；
Fig. 1 (c) is that man-made fracture induces tangential stress distribution curve at the borehole wall；
Fig. 1 (d) is total tangential stress distribution curve at the borehole wall after superposition；
In Fig. 1 (a)~Fig. 1 (d), abscissa is angle, and unit is angle value, and value range is 0-360 degree；Ordinate
Fig. 1 (a)~Fig. 1 (d) is followed successively by after drilling well shearing stress value at the borehole wall, injection fluid induce tangential stress value at the borehole wall, manually
Total tangential stress value, unit are at the borehole wall after induction tangential stress value, superposition at the borehole wall in crack：MPa.
Fig. 2 is fiber filter cake pressure difference with displacement variation curve；
In fig. 2, abscissa is the discharge capacity for injecting liquid, and unit is：Cube m/min, i.e. m3/min；Ordinate is
The pressure difference that fiber filter cake generates, unit are：MPa.
Specific implementation mode
In order to which technical characteristic, purpose and the advantageous effect to the present invention are more clearly understood, now to the skill of the present invention
Art scheme carry out it is described further below, but should not be understood as to the present invention can practical range restriction.
Embodiment 1
Such as 1 parameter of table, tangential stress distribution curve, injection fluid are successively simulated after A well drilling wells at the borehole wall at the borehole wall
It is always tangential at the borehole wall after inducing tangential stress distribution curve, man-made fracture to induce tangential stress distribution curve and superposition at the borehole wall
Distribution curve of stress, as shown in Fig. 1 Fig. 1 (a)~Fig. 1 (d), it can be seen that after first pressure break, at 90 degree (perpendicular to first tooled joint
Direction) borehole wall tangential stress minimum (196.8MPa), 0 degree (being parallel to just tooled joint direction) maximum (205.8MPa), the two difference
8MPa, since the tensile strength of A well rocks is 4.2MPa, fiber filter cake at least generates 12.2MPa pressure differences and can just block
First pressure-break, to generate new steering crack.
Fiber filter cake pressure difference changing rule under different injection discharge capacities is simulated, as shown in Fig. 2, when discharge capacity is higher than 1.3m3/
When min, fiber filter cake pressure difference is less than critical value 12.2MPa, thereby, it is ensured that scene injection fiber is temporarily less than to the discharge capacity of liquid
1.3m3/min.According to fibre concentration be 2%, calculate the temporary stall of fiber to the volume of liquid be 15~20m3。
1 A well basic input parameters tables of table
| Elasticity modulus | 38GPa | Poisson's ratio | 0.29 |
| Permeability Kx | 0.5mD | Permeability Ky | 0.5mD |
| Porosity | 0.065 | System compressibility | 3.45×10-4MPa-1 |
| Fracturing fluid viscosity | 300mPa·s | Initial reservoir pressure | 72MPa |
| Maximum horizontal principal stress | 144.8MPa | Minimum horizontal principal stress | 143.7MPa |
| Wellbore radius | 0.1m | Biot coefficients | 0.8 |
| Drainage radius | 200m | Bottom pressure | 152MPa |
A wells have carried out the temporary stall of fiber and have constructed to acid fracturing, are co-extruded into stratum liquid 636m3, first order prepad fluid is without communication
Display；Diversion agent in place after, low to squeeze into during stratum, pump pressure rises about 20MPa, in the fracturing fluid injection process of the second level,
Discharge capacity is not up to first order discharge capacity, and pump pressure is higher than the first order, and thinking realizes steering seam, though it is shown without linking up, but
Pump pressure declines to a great extent after acid filling, and reaction reservoir is slit formation.Termination of pumping pressure is 25.3MPa, and 24.7MPa is dropped to after 20min, is declined
0.6MPa.
Though A well acid fracturings, which are constructed, apparent communication, fluid is water in Reservoir Body.Residual acid empties after acid fracturing, sees a small amount of gas,
4mm oil nozzles, oil pressure 0.45MPa, daily output water 23.92m3/d.Test result：This section of acid fracturing reservoir is gassiness water layer.
The content that description in the present invention is not described in detail belongs to the prior art well known to professional and technical personnel in the field.
The above embodiment of the present invention is to cannot be used for the limitation present invention to the explanation of scheme, has protection domain comparable with the present invention
Any change in meaning and scope is all considered as including within the protection scope of the present invention.
Claims (3)
1. a kind of method for temporarily blocking up the optimal dosage of diversion agent in determining oil/gas well compact reservoir, this approach includes the following steps：
Step 1：Tangential stress after calculating drilling well on the borehole wall of oil/gas well, formula are as follows：
σθ0=-pw+(σH+σh)-2(σH-σh)cos(2θ) (1)
Wherein, pwFor shaft bottom fluid column static pressure, unit is megapascal；σHAnd σhFor far field maximum, minimum horizontal principal stress, unit is：
Megapascal；θ is polar angle, i.e., the angle in hole diameter direction and x-axis forward direction, unit are radian；
Step 2：At the borehole wall of oil/gas well, the tangential stress of injection flow-induced is calculated, formula is as follows：
σθ1=η (pw-p0) (2)
Wherein, pwFor shaft bottom fluid column static pressure, unit is megapascal；p0For original formation pressure, unit is megapascal；α
For Biot coefficient of elasticity, ν is Rock Poisson Ratio Using；
Step 3：At the borehole wall of oil/gas well, the stress difference for calculating man-made fracture induction is as follows：
△σy=ν (△ σx+△σz) (5)
In formula：
Wherein, rwFor wellbore radius, unit is rice；r1For polar diameter, the i.e. arithmetic square root of wellbore radius and the high quadratic sum of dummy joint,
Unit is rice；C is that dummy joint is high, and unit is rice；If θ1For negative value, then θ is used1+ π is replaced；P is net pressure in man-made fracture, unit
For megapascal；
Step 4：By stress transmission under step 3 rectangular co-ordinate at the stress under polar coordinates, obtain at the oil/gas well borehole wall, manually
The tangential stress of crack-induced, formula are as follows：
Step 5：By above formula (1), (2) and formula (8) phase simultaneous, you can obtain tangential around the oil/gas well borehole wall after the first pressure break
Stress distribution；
Step 6：According to rock elasticity fracture criteria, tangentially stress smallest point is opened and is split man-made fracture；Therefore, for must add
Enter crack after fiber and open from new direction to split, fiber filter cake parasitic pressure drop value must plus the sum of tangential stress at first time pressure-break
It must be more than the minimum of borehole wall tangential stress after first time pressure break, i.e.,
△pfiber+σθx≥σθ,min+T (9)
In formula, Δ pfiberIndicate fiber filter cake parasitic pressure drop value；Unit is megapascal；σθxIt indicates tangentially to answer at first time pressure-break
Power；Unit is megapascal；σθ,minThe minimum of borehole wall tangential stress after expression first time pressure break；Unit is megapascal；T indicates rock
Tensile strength, unit are megapascal；
So that it is determined that the optimal value of fiber filter cake parasitic pressure drop；
Step 7：Measure field fibre concentration is 2%, according to Darcy formula：Q=kA Δs P/ (μ L)=kwh Δs P/ (μ L) is calculated
Go out discharge capacity and is less than 1.5m3Corresponding optimal fiber filter cake length when/min.
Wherein, k is fiber Permeability；L is optimal fiber filter cake length；Unit is m；μ is fracturing fluid viscosity；Unit is：
Pa·s；Q is the discharge capacity for injecting fiber fracturing liquid, and unit is：m3/min；W is slit width, unit m；H is that dummy joint is high；Unit is
m；PKN or KGD (PKN can be passed through:Perkins-Kern-Nordgren；KGD:Khristianovic-Geertsma-de
Klerk takes initial) model or fracture software be calculated；Δ P is the fiber filter cake parasitic pressure drop obtained in the 6th step
Optimal value, unit are megapascal.
Step 8：By the optimal fiber filter cake length obtained in step 7, determination calculates optimal body of the temporary stall of fiber to liquid
Product for 2 × optimal fiber filter cake length × high ÷ fibre concentrations of slit width × seam, formula is as follows：
Vopt=2Lwh/n (10)
Wherein, n is that concentration, a concentration of quality volume fraction is added in fiber；L is fiber filter cake length；Unit is m；W is seam
Width, unit m；H is that dummy joint is high, unit m.
2. the method for claim 1, wherein the compact reservoir includes the shale in hot dry rock, untraditional reservoir
Gas, coal bed gas or fine and close oil and gas reservoir, the hyposmosis in conventional oil gas reservoir or super-low permeability reservoir.
3. the method as described in claim 1 and 2, wherein the oil/gas well includes straight well, horizontal well in above-mentioned compact reservoir
Or inclined shaft.
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| CN201711386760.0A CN108316915B (en) | 2017-12-20 | 2017-12-20 | Method for determining optimal dosage of fiber temporary plugging steering fluid in tight reservoir of oil and gas well |
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| CN201711386760.0A CN108316915B (en) | 2017-12-20 | 2017-12-20 | Method for determining optimal dosage of fiber temporary plugging steering fluid in tight reservoir of oil and gas well |
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Cited By (4)
| Publication number | Priority date | Publication date | Assignee | Title |
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| CN109267985A (en) * | 2018-09-26 | 2019-01-25 | 中国石油天然气股份有限公司 | A kind of control method of temporarily stifled turnaround fracture diverting agent dosage |
| US11397839B2 (en) * | 2019-06-12 | 2022-07-26 | Southwest Petroleum University | Method of particle size distribution of particulate bridging lost circulation materials for fractured leakage |
| CN115059441A (en) * | 2022-06-28 | 2022-09-16 | 中国石油化工集团有限公司 | Method for determining relation between pressure difference in gap and temporary plugging displacement in temporary plugging steering process |
| CN116124596A (en) * | 2023-04-20 | 2023-05-16 | 北京石油化工学院 | Method, device and storage medium for predicting crack plugging capability of temporary plugging agent |
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| CN109267985A (en) * | 2018-09-26 | 2019-01-25 | 中国石油天然气股份有限公司 | A kind of control method of temporarily stifled turnaround fracture diverting agent dosage |
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| US11397839B2 (en) * | 2019-06-12 | 2022-07-26 | Southwest Petroleum University | Method of particle size distribution of particulate bridging lost circulation materials for fractured leakage |
| CN115059441A (en) * | 2022-06-28 | 2022-09-16 | 中国石油化工集团有限公司 | Method for determining relation between pressure difference in gap and temporary plugging displacement in temporary plugging steering process |
| CN116124596A (en) * | 2023-04-20 | 2023-05-16 | 北京石油化工学院 | Method, device and storage medium for predicting crack plugging capability of temporary plugging agent |
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