CN103003520B - Method and system for treating a subterranean formation - Google Patents
Method and system for treating a subterranean formation Download PDFInfo
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- CN103003520B CN103003520B CN201180034234.2A CN201180034234A CN103003520B CN 103003520 B CN103003520 B CN 103003520B CN 201180034234 A CN201180034234 A CN 201180034234A CN 103003520 B CN103003520 B CN 103003520B
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- fluid
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- hypotonicity
- abrasive
- tracer
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Links
- 238000000034 method Methods 0.000 title claims abstract description 66
- 230000015572 biosynthetic process Effects 0.000 title abstract description 4
- 239000012530 fluid Substances 0.000 claims abstract description 119
- 239000000700 radioactive tracer Substances 0.000 claims abstract description 49
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 8
- 230000035699 permeability Effects 0.000 claims abstract description 8
- 230000008569 process Effects 0.000 claims description 27
- 238000012544 monitoring process Methods 0.000 claims description 4
- 239000011159 matrix material Substances 0.000 claims description 3
- 238000005259 measurement Methods 0.000 claims description 3
- 230000000638 stimulation Effects 0.000 description 34
- 238000002347 injection Methods 0.000 description 25
- 239000007924 injection Substances 0.000 description 25
- 238000010992 reflux Methods 0.000 description 17
- 238000005070 sampling Methods 0.000 description 15
- 239000000203 mixture Substances 0.000 description 13
- 230000000694 effects Effects 0.000 description 12
- 238000004140 cleaning Methods 0.000 description 11
- 238000004458 analytical method Methods 0.000 description 10
- 230000008859 change Effects 0.000 description 9
- 238000004519 manufacturing process Methods 0.000 description 8
- 239000000126 substance Substances 0.000 description 8
- 238000013461 design Methods 0.000 description 4
- 238000005516 engineering process Methods 0.000 description 4
- 238000012545 processing Methods 0.000 description 4
- 230000008901 benefit Effects 0.000 description 3
- 238000010586 diagram Methods 0.000 description 2
- 238000006073 displacement reaction Methods 0.000 description 2
- 238000009826 distribution Methods 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 230000003252 repetitive effect Effects 0.000 description 2
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 1
- 235000019738 Limestone Nutrition 0.000 description 1
- 238000012790 confirmation Methods 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 230000002596 correlated effect Effects 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 239000010459 dolomite Substances 0.000 description 1
- 229910000514 dolomite Inorganic materials 0.000 description 1
- 230000006870 function Effects 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 230000005764 inhibitory process Effects 0.000 description 1
- 239000006028 limestone Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 229910001425 magnesium ion Inorganic materials 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000013011 mating Effects 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 238000002203 pretreatment Methods 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/10—Locating fluid leaks, intrusions or movements
- E21B47/11—Locating fluid leaks, intrusions or movements using tracers; using radioactivity
Abstract
A method and apparatus to treat a subterranean formation comprising a wellbore including introducing a tool to a wellbore in a region of low permeability or damage, treating the region of low permeability or damage with a fluid, simultaneously measuring a fluid pressure drop and volume of fluid flow in a particular region, and moving the tool to another region. A method and apparatus to treat a subterranean formation comprising a wellbore including introducing to a wellbore a tool in a region of low permeability or damage, treating the region of low permeability or damage with a fluid, introducing a diversion agent, and moving the tool to another region wherein the fluid comprises a tracer.
Description
Background technology
Fracturing and/or matrix acidizing oil and gas well are through being usually used in from making production increase production more than one deck identical pit shaft.Exist many for guaranteeing the technology that stimulation treatment and (several) other layer are isolated.These technology have the cost of different stage, complexity, reliability and time loss.Because current limiting technique relates to do not confirm that fluid settled efficiency to be just placed in stratum by inlet point, so described current limiting technique is never best before volume increase.
Summary of the invention
Embodiment of the present invention relate to a kind of method that process comprises the stratum of pit shaft, it comprises: in hypotonicity or abrasive area, instrument is introduced into pit shaft, utilize fluid treatment hypotonicity or abrasive described area, measure fluid pressure drop and the volume of the fluid flowing in particular locality simultaneously, and described instrument is moved to another area.Embodiment of the present invention relate to a kind of method that process comprises the stratum of pit shaft, it comprises: in hypotonicity or abrasive area, instrument is introduced into pit shaft, utilize fluid treatment hypotonicity or abrasive described area, introduce diversion agent, and described instrument is moved to another area, wherein said fluid comprises tracer.
Accompanying drawing explanation
Fig. 1 is the sectional view of the instrument in pit shaft.
Fig. 2 is the sectional view of the instrument in pit shaft.
Fig. 3 is the curve map of the pressure according to injection rate.
Fig. 4 is the sectional view of the instrument in pit shaft.
Fig. 5 is the sectional view of pit shaft.
Fig. 6 is the curve map of the pressure according to injection rate.
Fig. 7 is the sectional view of the instrument in pit shaft.
Fig. 8 is the sectional view of pit shaft.
Detailed description of the invention
When starting, should note in the exploitation of any actual embodiment like this, must make many embodiments-specific decision to realize the specific objective of developer, system of such as following is correlated with the constraint relevant with business, and described target is different because of the difference of embodiment.And should understand that such development may be complicated and consuming time, even so, but be a routine mission for the one of ordinary skill in the art benefiting from present disclosure.In addition, use/disclosed composition can also comprise the component except the component of citation herein.In the present invention and this summary described in detail, unless separately had instruction within a context, otherwise each numerical value modified by term " approximately " should be read once (unless modifying so clearly), and then not that the numerical value modified like this is read again.Also in the present invention and this summary described in detail, should be understood that listing or be described as useful, suitable etc. concentration range expects that any and each concentration comprised in the scope of end points should be considered to state.Such as, " scope from 1 to 10 " is taken as each and each possibility numeral indicated the continuous number between about 1 and about 10.Therefore, even if the particular data point in scope or just some specific detail even not having the data point in scope to be clearly identified or refer to, should understand, inventor understands and any and all data points within the scope of understanding are considered to be designated, and inventor have in gamut and scope understanding a little.The statement made herein is only to provide and cuts relevant information in the disclosure and do not form prior art, and can describe diagram embodiments more of the present invention.
Embodiment of the present invention can make and utilize less wellbore operations, more reliable and predictably and all the time under less cost and time, use current limiting technique to process the system in multiple district.Embodiment of the present invention are to the improvement of the process of establishing of restricted zone volume increase and solve by the shortcoming of the unpredictability in multiple districts of increasing production, efficiency and confirmation.This be one can to the method for each inlet point test fluid flow acceptance fast, reliably and cheaply.
This is a method simultaneously making multiple fracturing sections volume increase in multiple district or same zone and/or acidifying.Process relates to will make each district or several packet zone be processed together, makes to process be isolated and can not enter district's well in first pre-treatment/perforation district.How this more can will pay its production to each district controls.
1. process will start from conventional current limliting design to determine that each fracturing section is by the suitable of the volume increase of generation and optimised quantity.
2. then, initial access aperture or groove will enter in a district.Ideally, this is by the district of pending minimal pressure split pressure.But this is effective in any possibility pressure break point needing restriction flowing.Then these some some places entered entering in region the design being equal to or less than this point are produced (Fig. 1).During this step, some embodiments can benefit from the use of tracer.
3., when observing and record with different rates and pressure pumping, perforation or injection apparatus will be stayed in hole with continuation operation (Fig. 2).This enters to ingress rate in fracturing section to pressure (Fig. 3) with the fracturing section produced under being used for being aligned in the real time rate according to the time by given.Pressure should with maximum accuracy in the opereating specification of expection process.
4. following, perforation or grooving apparatus move to the second pressure break point and repetitive process (step 2 and 3).Now advance the speed to realize uniform pressure scope (Fig. 4, Fig. 5, Fig. 6).The speed difference (first rate and the second speed) at uniform pressure place enters to the fluid rate in the secondth district.That is, difference instruction real-time fluid behavior.Some embodiments can perform perforation step, are then injecting steps.Some extra embodiments can perform injecting step, are perforation step afterwards.
5. can in repetitive process in more multi-region until realize maximum admissible speed for district.Some embodiments can benefit from the use of shunting treatment step.
If 6. another district relatively, needs major part process to be put in a district, so when slot or perforating system still in the wellbore, add (several) another inlet point.
If 7. determine that the inlet point of limited quantity carries out process and will limit oil or natural gas and produce, so when perforation or grooving apparatus at pit shaft, added holes.
8. realize, comparatively after low prepared surface pressure, during main frac treatment, removing perforation or grooving apparatus from well.Fig. 7 also illustrate how to adjust instrument size to promote that fluid flows through pit shaft.Fig. 8 diagram is used for the cleanup step of embodiments more of the present invention.
If 9. realize maximum rate and exist still needing time interval of pressure break or volume increase, so conventional shunting or plugging material, packer or bridging plug may be used for making these separate from.
10., in order to add fast process, can not stop carrying out step 2 under pumping or frac treatment to step 5.In this version, produce initial apertures, meet admissible processing pressure, while maintenance pressure, hole is placed in other district (or same zone).Difference is the speed at new bore place.Repeat step until suitably process required all districts or realize maximum rate.
Embodiment of the present invention also allow to measure shunting thing making volume increase and dirty treat liquid distinguish from high osmosis and flow to hypotonicity district, or branch to low-pressure area from higher-pressure region, or the effect from the layer with high fluid mobility branches to the layer with lower fluid mobility.Embodiment of the present invention also more uniformly settle the chemicals of injection for assessment of effect or shunting thing to cross to have heterogeneity and can affect the layer that chemicals settles.Method allows to calculate in high osmosis layer in low permeability layer, or in low-pressure area in higher-pressure region, or fluid there is compared with high fluidity layer in convection cell there is compared with lazy flow layer in the fluid volume injected and well resume production after cleaning or degree of back flow.That is, by the illustrated different pressures of Fig. 3 and Fig. 6 distribute show more perforations and/or pressure break how to affect cause the pressure observed and provide estimating along the flow distribution of pit shaft and the method for pressure.
Cleaning degree after method allows calculating low permeability layer to resume production to the fluid volume injected in high osmosis layer and well.Consider the stimulation treatment being designed to two reservoir regions that pit shaft intersects.Suppose that top region is high osmosis district (or low-pressure area or the higher district of fluid mobility) and bottom zone is hypotonicity district (or higher-pressure region or the lower district of fluid mobility).Object measures in Liang Ge district the stimulation fluid or scale inhibition fluid volume (estimating shunting thing efficiency) of injecting and cleaning effect during determining to reflux.This method also allows the alternative substituting the conventional method using distributed temperature sensor (DTS).
In order to confirm the effect of this system (or current limiting technique), consider the stimulation treatment being designed to two reservoir regions that pit shaft intersects.Suppose that top region is high osmosis district and bottom zone is hypotonicity district.Object measures in hypotonicity district the stimulation fluid or volume (estimating shunting thing efficiency) of injecting and cleaning effect during determining to reflux.To comprise the following steps according to the estimation of embodiment of the present invention:
1. injection has the stimulation fluid S1 of tracer T1.
2. the injection shunting thing stage.
3. injection has the stimulation fluid S2 of tracer T2.
4. the location well sampling device between top region and bottom zone, the compact such as with multiple sampling bottle produces sampling box.
5. to be back in well and during refluxing, to collect surface sample and downhole samples and record flow velocity during refluxing.
6. analyze the composition of surface sample and downhole samples.
7. by determining the stimulation fluid volume injected in period first stage (S1 fluid) lower district in analysis surface sample to the tracer T1 concentration in downhole samples.
8. by analyzing the stimulation fluid volume in surface sample, the tracer concentration in downhole samples being determined to the injection of period in the second volume increase stage (S2 fluid) for tracer T2.
9. pair flow velocity is quadratured with Fluid Computation volume.
10. compare from 7 to 9 result to determine the effect in shunting stage.
11. cleaning efficiencies determining each district by assigning to the flow velocity quadrature of the stimulation fluid of fetching from each district.
Tracer concentration can be measured by monitoring and concentration dependent fluid properties (such as pH, resistivity, density, color etc.).Can a single point in flow path or multiple somes places measure.Can improve process design in carry out in real time and uses measurement or measured value can be stored to memory and after a while analyzed be used for improve future design.
The tracer used in monitoring shunting can from stratum self.Such as, may in carbonate reservoir, hypotonicity district has more dolomite CaMg (CO
3), and high osmosis district has more limestone (CaCO
3).In this case, Ca and Mg can be used as tracer and concentration in its reflux fluid may be used for determining shunting thing efficiency.
Once carry out the measurement of tracer concentration, the method for the U.S. Patent number 7658226 be incorporated herein by reference in full may be used for calculating shunting thing efficiency.Additional embodiments can benefit from application on December 10th, 2009, be called " Method of Determining EndMember Concentrations " and the U.S. Patent Application No. 12/635 be incorporated herein by reference in full, the alternate embodiment described in 002.For calculate shunting efficiency alternative be by suppose certain shunting thing efficiency and then contrast measured value compare calculating concentration and then repeatedly adjustment shunting thing efficiency until obtain good mating between calculated value with measured value, whole process is increased production.
---change 1
Can combine above with the PLT that locates in lower district.
---change 2
1) injection has the stimulation fluid S1 of tracer T1.
2) inject and the stimulation fluid utilizing the shunting stage S2 of tracer T2 to mix.
3) the location well sampling device between top region and bottom zone, the compact such as with multiple sampling bottle produces sampling box.
4) to be back in well and during refluxing, to collect surface sample and downhole samples and record flow velocity during refluxing.
5) composition of surface sample and downhole samples is analyzed.
6) by determining the stimulation fluid volume injected in period first stage (S1 fluid) lower district in analysis surface sample to the tracer T1 concentration in downhole samples.
7) by analyzing the stimulation fluid volume in surface sample, the tracer concentration in downhole samples being determined to the injection of period in the second volume increase stage (S2 fluid) for tracer T2.
8) flow velocity is quadratured with Fluid Computation volume.
9) compare from 6 to 8 result to determine the effect in shunting stage.
10) cleaning efficiency in each district is determined by assigning to the flow velocity quadrature of the stimulation fluid of fetching from each district.
---change 3
The PLT that (change 2) above and lower district locate can be combined.
---change 4
1) stimulation fluid mixed with the shunting chemicals S1 with tracer T1 is injected.
2) injection has fluid S2 (such as, displacement fluid, displacement fluid, rearmounted fluid) after the volume increase of tracer T2.
3) the location well sampling device between top region and bottom zone, the compact such as with multiple sampling bottle produces sampling box.
4) to be back in well and during refluxing, to collect surface sample and downhole samples and record flow velocity during refluxing.
5) composition of surface sample and downhole samples is analyzed.
6) by determining the stimulation fluid volume injected in first stage (S1 fluid) period Liang Ge district in analysis surface sample to the tracer T1 concentration in downhole samples.
7) by analyzing for tracer T2 in surface sample, fluid volume after the volume increase of second stage (S2 fluid) period injection is determined to the tracer concentration in downhole samples.
8) flow velocity is quadratured with Fluid Computation volume.
9) compare from 6 to 8 result to determine to shunt the effect of chemicals.
10) cleaning efficiency in each district is determined by assigning to the flow velocity quadrature of the stimulation fluid of fetching from each district.
---change 5
The PLT that (change 4) above and lower district locate can be combined.
---change 6
1) injection has the pre-stimulation fluid S1 (such as, reservoir regulates or preconditioning fluid) of tracer T1.
2) main stimulation fluid shunted thing S2 with the chemistry with tracer T2 and mix is injected.
3) the location well sampling device between top region and bottom zone, the compact such as with multiple sampling bottle produces sampling box.
4) to be back in well and during refluxing, to collect surface sample and downhole samples and record flow velocity during refluxing.
5) composition of surface sample and downhole samples is analyzed.
6) by determining the pre-stimulation fluid volume injected in period first stage (S1 fluid) lower district in analysis surface sample to the tracer T1 concentration in downhole samples.
7) by analyzing the main stimulation fluid volume in surface sample, the tracer concentration in downhole samples being determined to the second injection stage (S2 fluid) period injection for tracer T2.
8) flow velocity is quadratured with Fluid Computation volume.
9) compare from 6 to 8 result to determine that the chemistry mixed with primary processing fluid shunts the effect of thing.
10) cleaning efficiency in each district is determined by assigning to the flow velocity quadrature of the stimulation fluid of fetching from each district.
---change 7
The PLT that (change 4) above and lower district locate can be combined.
---change 8
Step 1 in above change 2,4 and 6 can be combined to 2 and following steps:
3. to be back in well and during refluxing, to collect surface sample and record flow velocity during refluxing.
4. analyze the composition of surface sample.
5. the stimulation fluid volume injected in period first stage (S1 fluid) lower district is determined by the tracer T1 concentration analyzed in surface sample.
6. the tracer concentration by analyzing in surface sample for tracer T2 determines fluid volume after the volume increase of second stage (S2 fluid) period injection.
7. pair flow velocity is quadratured with Fluid Computation volume.
8. compare from 5 to 7 result to determine to shunt the effect of chemicals.
9. the cleaning efficiency in each district is determined by assigning to the flow velocity quadrature of the stimulation fluid of fetching from each district.
---change 9
1) injection has the pre-stimulation fluid S1 (such as, reservoir regulates or preconditioning fluid) of tracer T1.
2) main stimulation fluid shunted thing S2 with the chemistry with tracer T2 and mix is injected.
3) injection has fluid S3 after the volume increase of tracer T3 (such as, reservoir regulates or preconditioning fluid).
4) the location well sampling device between top region and bottom zone, the compact such as with multiple sampling bottle produces sampling box.
5) to be back in well and during refluxing, to collect surface sample and downhole samples and record flow velocity during refluxing.
6) composition of surface sample and downhole samples is analyzed.
7) by determining the pre-stimulation fluid volume injected in period first stage (S1 fluid) lower district in analysis surface sample to the tracer T1 concentration in downhole samples.
8) by analyzing the main stimulation fluid volume in surface sample, the tracer concentration in downhole samples being determined to the second injection stage (S2 fluid) period injection for tracer T2.
9) by analyzing for tracer T3 in surface sample, fluid volume after the volume increase of the 3rd injection stage (S3 fluid) period injection is determined to the tracer concentration in downhole samples.
10) flow velocity is quadratured with Fluid Computation volume.
11) compare from 7 to 10 result to determine that the chemistry mixed with primary processing fluid shunts the effect of thing.
12) cleaning efficiency in each district is determined by assigning to the flow velocity quadrature of the stimulation fluid of fetching from each district.
---change 10
Step 1 in change 9 can be combined to 3 and following steps:
4. to be back in well and during refluxing, to collect surface sample and record flow velocity during refluxing.
5. analyze the composition of surface sample.
6. by determining the pre-stimulation fluid volume injected in period first stage (S1 fluid) lower district in analysis surface sample to the tracer T1 concentration in downhole samples.
7. by analyzing the main stimulation fluid volume in surface sample, the tracer concentration in downhole samples being determined to the second injection stage (S2 fluid) period injection for tracer T2.
8. by analyzing for tracer T3 in surface sample, fluid volume after the volume increase of period phase III (S3 fluid) injection is determined to the tracer concentration in downhole samples.
9. pair flow velocity is quadratured with Fluid Computation volume.
10. compare from 6 to 9 result to determine to shunt the effect of chemicals.
11. cleaning efficiencies determining each district by assigning to the flow velocity quadrature of the stimulation fluid of fetching from each district.
---change 11
The PLT that (change 9 and change 10) above and lower district locate can be combined.
---change 12
Can combine above all and usually sample to estimate that the chemicals shunting thing efficiency and treatment effeciency returns distributional analysis value in top side.
---change 13
Can combine above all with may be present in pretreatment fluid, after primary processing fluid and/or process in fluid to estimate the backflow character (speed and concentration) being labeled chemicals and the flow distribution of shunting thing efficiency and treatment effeciency for a long time.
Equally, when the composition of analysis of downhole fluids sample and surfactant fluid sample, we should analyze whole composition.Such as, except searching T1 and T2, we should search from shunting Ca, Mg ion in stage and any component.It is most likely that low permeability formation will in Composition Aspects difference (can comprise more dolomites), and then the analysis of Ca/Mg concentration will allow us at the flow velocity without the need to calculating under PLT from hypotonicity district.Analysis for the component of shunting thing can also cause similar results.The concentration of T1 and T2 need not be constant.Step in T1 and T2 concentration or the use on slope or feasible.The use of mass balance tracer T3 can also be used for the amount of the stimulation fluid confirming to resume production.
Some illustrative embodiment of the concept of reference present inventor describe before presenting.The technician of this area belonging to the present invention and science and technology will understand, can not depart from the change in the description scheme of practical operation under principle of the present invention and category and method and change in meaning.Therefore, previous description only should not belong in accompanying drawing and describes and shown precision architecture, but should do to make peace with following claim one of the most fair category support following claim the most completely with by having it.
In addition, the description in subject application should not imply that any particular element, step or function are the required elements that must be included in claim categories: the category of patent purport only defined by the claim allowed.And, unless follow word accurately " for ... means " after be participle, otherwise and undesirably these claims call the 6th section of 35USC § 112.Expect that the claim of applying for is comprehensive as far as possible, and do not abandon wittingly, be devoted to or abandon purport.
Claims (20)
1. process comprises the method on the stratum of pit shaft, and it comprises:
At hypotonicity or abrasive area, instrument is introduced into pit shaft;
Utilize fluid treatment hypotonicity or abrasive described area;
Measure fluid pressure drop and the volume of the fluid flowing of particular locality simultaneously;
And described instrument is moved to another area.
2. method according to claim 1, it comprises the character in described fluid pressure drop and volume computing hypotonicity or the abrasive described area using fluid to flow further.
3. method according to claim 1, wherein said process hypotonicity or abrasive described area comprise makes the volume increase of described area.
4. method according to claim 3, wherein makes the volume increase of described area comprise matrix acidizing process, fracturing process, introduces proppant or its combination.
5. method according to claim 1, its comprise further utilize described fluid introduce tracer.
6. method according to claim 1, it comprises process described in repetition and the step of mobile described instrument further.
7. method according to claim 1, wherein said instrument has the size allowing fluid to flow through described pit shaft.
8. process comprises the method on the stratum of pit shaft, and it comprises:
At hypotonicity or abrasive area, instrument is introduced into pit shaft;
Utilize fluid treatment hypotonicity or abrasive described area;
Introduce diversion agent;
And described instrument is moved to another area,
Wherein said fluid comprises tracer.
9. method according to claim 8, wherein said diversion agent comprises tracer.
10. method according to claim 8, it comprises the fluid pressure drop and volume of measuring fluid flowing further simultaneously.
11. methods according to claim 10, it comprises the character in described fluid pressure drop and volume computing hypotonicity or the abrasive described area using fluid to flow further.
12. methods according to claim 8, wherein said process hypotonicity or abrasive described area comprise makes the volume increase of described area.
13. methods according to claim 12, wherein make the volume increase of described area comprise matrix acidizing process, fracturing process, introduce proppant or its combination.
14. 1 kinds of process comprise the method on the stratum of pit shaft, and it comprises:
At hypotonicity or abrasive area, instrument is introduced into pit shaft;
Utilize fluid treatment hypotonicity or abrasive described area;
Introduce diversion agent;
Monitor described fluid, wherein said fluid comprises tracer; And
Described instrument is moved to other area.
15. methods according to claim 14, it comprises the described fluid of assessment further.
16. methods according to claim 15, wherein assess described fluid and comprise the permeability estimating hypotonicity or abrasive described area.
17. methods according to claim 14, wherein said monitoring comprises the concentration measuring tracer.
18. methods according to claim 17, it comprises the character in fluid pressure drop and volume computing hypotonicity or the abrasive described area using fluid to flow further.
19. methods according to claim 14, the described fluid of wherein said monitoring comprises measurement parameter to estimate diversion agent character.
20. methods according to claim 19, wherein said diversion agent character comprises the validity of described diversion agent.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US33346810P | 2010-05-11 | 2010-05-11 | |
| US61/333,468 | 2010-05-11 | ||
| PCT/IB2011/052060 WO2011141875A2 (en) | 2010-05-11 | 2011-05-10 | Method and system for treating a subterranean formation |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN103003520A CN103003520A (en) | 2013-03-27 |
| CN103003520B true CN103003520B (en) | 2015-05-13 |
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ID=44914767
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201180034234.2A Expired - Fee Related CN103003520B (en) | 2010-05-11 | 2011-05-10 | Method and system for treating a subterranean formation |
Country Status (8)
| Country | Link |
|---|---|
| US (1) | US20140166276A1 (en) |
| EP (1) | EP2564020A4 (en) |
| CN (1) | CN103003520B (en) |
| AU (2) | AU2011251674B2 (en) |
| CA (1) | CA2799098A1 (en) |
| EA (1) | EA025825B1 (en) |
| MX (1) | MX2012013138A (en) |
| WO (1) | WO2011141875A2 (en) |
Families Citing this family (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2013078031A1 (en) * | 2011-11-22 | 2013-05-30 | Baker Hughes Incorporated | Method of using controlled release tracers |
| US9850714B2 (en) * | 2015-05-13 | 2017-12-26 | Baker Hughes, A Ge Company, Llc | Real time steerable acid tunneling system |
| RU2705012C1 (en) * | 2015-11-03 | 2019-11-01 | ВЕЗЕРФОРД ТЕКНОЛОДЖИ ХОЛДИНГЗ, ЭлЭлСи | Systems and methods for estimating and optimizing efficiency of stimulation using bypass devices |
| US9810063B2 (en) | 2015-11-12 | 2017-11-07 | King Fahd University Of Petroleum And Minerals | Method for evaluating the effectiveness of matrix acidizing in a subterranean formation |
| CN108222922B (en) * | 2016-12-14 | 2021-06-01 | 中国石油天然气股份有限公司 | Oil-gas well reservoir productivity evaluation method based on temporary blocking diversion fracturing technology |
| CN108756841B (en) * | 2018-04-18 | 2020-03-24 | 中国科学院武汉岩土力学研究所 | Shale repeated fracturing treatment method |
| CN113530509A (en) * | 2020-04-15 | 2021-10-22 | 中国石油天然气股份有限公司 | Continuous separate-layer fracturing method for small well and fracturing pipe column |
| RU2750004C1 (en) * | 2020-11-20 | 2021-06-21 | Публичное акционерное общество «Татнефть» имени В.Д. Шашина | Method for completing and intensifying inflow of well with carbonate reservoirs |
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2011
- 2011-05-10 EA EA201291215A patent/EA025825B1/en not_active IP Right Cessation
- 2011-05-10 EP EP11780291.8A patent/EP2564020A4/en not_active Withdrawn
- 2011-05-10 WO PCT/IB2011/052060 patent/WO2011141875A2/en active Application Filing
- 2011-05-10 AU AU2011251674A patent/AU2011251674B2/en not_active Ceased
- 2011-05-10 US US13/697,460 patent/US20140166276A1/en not_active Abandoned
- 2011-05-10 MX MX2012013138A patent/MX2012013138A/en unknown
- 2011-05-10 CA CA2799098A patent/CA2799098A1/en not_active Abandoned
- 2011-05-10 CN CN201180034234.2A patent/CN103003520B/en not_active Expired - Fee Related
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2016
- 2016-06-23 AU AU2016204275A patent/AU2016204275A1/en not_active Abandoned
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| US4867241A (en) * | 1986-11-12 | 1989-09-19 | Mobil Oil Corporation | Limited entry, multiple fracturing from deviated wellbores |
| US5141054A (en) * | 1991-03-13 | 1992-08-25 | Mobil Oil Corporation | Limited entry steam heating method for uniform heat distribution |
| CN101418680A (en) * | 2007-10-23 | 2009-04-29 | 王长俊 | Gas lift unblocking technology by chemical method |
| CN101560879A (en) * | 2008-04-15 | 2009-10-21 | 中国石油大学(北京) | Well test analysis control method for low permeability gas reservoir and method thereof |
Also Published As
| Publication number | Publication date |
|---|---|
| WO2011141875A2 (en) | 2011-11-17 |
| WO2011141875A3 (en) | 2012-02-16 |
| AU2016204275A1 (en) | 2016-07-14 |
| EA025825B1 (en) | 2017-02-28 |
| AU2011251674A1 (en) | 2012-12-06 |
| AU2011251674B2 (en) | 2016-03-24 |
| US20140166276A1 (en) | 2014-06-19 |
| CN103003520A (en) | 2013-03-27 |
| EP2564020A2 (en) | 2013-03-06 |
| EP2564020A4 (en) | 2017-07-19 |
| CA2799098A1 (en) | 2011-11-17 |
| MX2012013138A (en) | 2012-12-17 |
| EA201291215A1 (en) | 2013-06-28 |
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