CN104265211A - Method Of Using Pressure Signatures To Predict Injection Well Anomalies - Google Patents
Method Of Using Pressure Signatures To Predict Injection Well Anomalies Download PDFInfo
- Publication number
- CN104265211A CN104265211A CN201410356336.1A CN201410356336A CN104265211A CN 104265211 A CN104265211 A CN 104265211A CN 201410356336 A CN201410356336 A CN 201410356336A CN 104265211 A CN104265211 A CN 104265211A
- Authority
- CN
- China
- Prior art keywords
- pressure
- crackle
- rock stratum
- signature
- well
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
- 238000000034 method Methods 0.000 title claims abstract description 57
- 238000002347 injection Methods 0.000 title claims abstract description 42
- 239000007924 injection Substances 0.000 title claims abstract description 42
- 239000000243 solution Substances 0.000 claims abstract description 15
- 230000004044 response Effects 0.000 claims abstract description 7
- 208000037656 Respiratory Sounds Diseases 0.000 claims description 71
- 239000011435 rock Substances 0.000 claims description 54
- 238000003860 storage Methods 0.000 claims description 28
- 230000007423 decrease Effects 0.000 claims description 7
- 239000013535 sea water Substances 0.000 claims description 4
- 230000000007 visual effect Effects 0.000 claims 1
- 230000015572 biosynthetic process Effects 0.000 abstract description 14
- 238000005520 cutting process Methods 0.000 abstract 2
- 238000005553 drilling Methods 0.000 description 36
- 230000008569 process Effects 0.000 description 27
- 239000012530 fluid Substances 0.000 description 26
- 230000035882 stress Effects 0.000 description 23
- 238000007789 sealing Methods 0.000 description 11
- 239000007787 solid Substances 0.000 description 10
- 230000008859 change Effects 0.000 description 8
- 238000005336 cracking Methods 0.000 description 6
- 230000007704 transition Effects 0.000 description 6
- 230000000903 blocking effect Effects 0.000 description 5
- 238000004458 analytical method Methods 0.000 description 4
- 238000013461 design Methods 0.000 description 4
- 238000012545 processing Methods 0.000 description 4
- 230000004308 accommodation Effects 0.000 description 3
- 239000004568 cement Substances 0.000 description 3
- 230000000694 effects Effects 0.000 description 3
- 230000007246 mechanism Effects 0.000 description 3
- 238000003825 pressing Methods 0.000 description 3
- 230000000644 propagated effect Effects 0.000 description 3
- 239000004576 sand Substances 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 230000006835 compression Effects 0.000 description 2
- 238000007906 compression Methods 0.000 description 2
- 230000002596 correlated effect Effects 0.000 description 2
- 230000006378 damage Effects 0.000 description 2
- 238000003745 diagnosis Methods 0.000 description 2
- 239000012065 filter cake Substances 0.000 description 2
- 230000002706 hydrostatic effect Effects 0.000 description 2
- 238000002513 implantation Methods 0.000 description 2
- 230000007774 longterm Effects 0.000 description 2
- 239000003129 oil well Substances 0.000 description 2
- 239000002245 particle Substances 0.000 description 2
- 230000000630 rising effect Effects 0.000 description 2
- 238000004062 sedimentation Methods 0.000 description 2
- 238000004088 simulation Methods 0.000 description 2
- 230000000638 stimulation Effects 0.000 description 2
- 239000000725 suspension Substances 0.000 description 2
- LENZDBCJOHFCAS-UHFFFAOYSA-N tris Chemical compound OCC(N)(CO)CO LENZDBCJOHFCAS-UHFFFAOYSA-N 0.000 description 2
- 206010011376 Crepitations Diseases 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 230000002547 anomalous effect Effects 0.000 description 1
- 230000033228 biological regulation Effects 0.000 description 1
- 230000005540 biological transmission Effects 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000001816 cooling Methods 0.000 description 1
- 230000018044 dehydration Effects 0.000 description 1
- 238000006297 dehydration reaction Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000007599 discharging Methods 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 239000012634 fragment Substances 0.000 description 1
- 239000007943 implant Substances 0.000 description 1
- 230000008595 infiltration Effects 0.000 description 1
- 238000001764 infiltration Methods 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 238000013508 migration Methods 0.000 description 1
- 230000005012 migration Effects 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 239000002244 precipitate Substances 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 239000000047 product Substances 0.000 description 1
- 230000001902 propagating effect Effects 0.000 description 1
- 238000012216 screening Methods 0.000 description 1
- 239000010802 sludge Substances 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
- 230000003068 static effect Effects 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
- 230000008646 thermal stress Effects 0.000 description 1
- 238000012546 transfer Methods 0.000 description 1
- 230000001052 transient effect Effects 0.000 description 1
- 239000002699 waste material Substances 0.000 description 1
Classifications
-
- 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
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
-
- 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
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/06—Arrangements for treating drilling fluids outside the borehole
- E21B21/063—Arrangements for treating drilling fluids outside the borehole by separating components
- E21B21/065—Separating solids from drilling fluids
- E21B21/066—Separating solids from drilling fluids with further treatment of the solids, e.g. for disposal
-
- 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
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/01—Arrangements for handling drilling fluids or cuttings outside the borehole, e.g. mud boxes
-
- 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
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/005—Waste disposal systems
- E21B41/0057—Disposal of a fluid by injection into a subterranean formation
-
- 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
- E21B49/008—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 by injection test; by analysing pressure variations in an injection or production test, e.g. for estimating the skin factor
Landscapes
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- Geochemistry & Mineralogy (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Mechanical Engineering (AREA)
- Analytical Chemistry (AREA)
- Chemical & Material Sciences (AREA)
- Processing Of Solid Wastes (AREA)
- Investigating Strength Of Materials By Application Of Mechanical Stress (AREA)
- Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
- Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
- Measuring Fluid Pressure (AREA)
- Underground Structures, Protecting, Testing And Restoring Foundations (AREA)
Abstract
A method of designing a response to a fracture behavior of a formation during re-injection of cuttings into a formation, the method including obtaining a pressure signature for a time period, interpreting the pressure signature for the time period to determine a fracture behavior of the formation, determining a solution based on the fracture behavior of the formation, and implementing the solution is disclosed. A method of assessing a subsurface risk of a cuttings re-injection operation, the method including obtaining a pressure signature for a time period, interpreting the pressure signature to determine a fracture behavior of the formation, characterizing a risk associated with the determined fracture behavior of the formation, and implementing a solution based on the characterized risk is also disclosed.
Description
Technical field
The embodiment disclosed herein relates generally to the method determining the fracture behaviour processing stratum or rock stratum during CRI operation.
Background technology
In drilling well, drill bit is used to pierce earth's crust several thousand feet.Usually, oil rig adopts the derrick extended on offshore boring island.During drill-well operation, the drill pipe joints (joint) after the joint of the drilling pipe that derrick supporting base end portion connects to end.When drill bit deeper advances to underground, additional drilling pipe is added to " tubing string " or " drill string or drill set " that constantly lengthen.Therefore, drill string comprises the joint of multiple drilling pipe.
Fluid " drilling mud " to be drawn into from offshore boring island by drill string or drill set and to be supported on the lower end of drill string or the drill bit of end.Drilling mud makes drill bit lubricate, and takes away the well drilling detritus that drill bit produces when piercing darker.Carried by the backflow of drilling mud by this landwaste of well annulus, and return the offshore boring island of surface of stratum.When drilling mud arrives platform, drilling mud is mixed with the fractionlet of industrial known shale and rock and fragment or well drilling detritus.Once well drilling detritus, drilling mud and other discarded objects arrive platform, usually use " mud vibrating screen (shale shaker) " to remove drilling mud from well drilling detritus, drilling mud can be recycled.Then, remaining well drilling detritus, discarded object, and the drilling mud of remnants is transferred to storagetank and processes.In some cases, the drilling mud of such as particular types, drilling mud can not recycle and must be processed.Usually, expendable drilling mud and well drilling detritus be separated with other discarded objects process by utilizing container drilling mud to be transported to process place.
The process of well drilling detritus and drilling mud is a complex environment problem.Well drilling detritus not only comprises the drilling mud product that surrounding environment is polluted in remaining meeting, particularly in marine environment during drilling well, also may comprise the oil and other refuses that are harmful to especially environment.
A kind of method of the landwaste of process oily sludge is, adopts landwaste re-injection (CRI) operation to be recycled in stratum or rock stratum by landwaste.The basic step of this process comprises the stratum or rock stratum that identify and be applicable to injecting; Prepare suitable Injection Well; Preparation mud, comprises and considers such as weight, solid content, pH, the factors such as gel; Implement implant operation, comprise and determine and monitor pump speed, the volume of such as time per unit and pressure; And Gai Jing.
Therefore, a kind of method determining the fracture behaviour processing rock stratum in CRI operation is needed.
Summary of the invention
On the one hand, the embodiment disclosed herein relates to a kind of design in the method responding fracturation behavior during rock stratum re-injection landwaste, and described method comprises: the pressure signature obtaining a time period; Explain that the pressure signature of this time period is to determine the fracture behaviour of described rock stratum; Based on fracture behaviour determination a solution of described rock stratum; And implement described solution.
On the other hand, the embodiment disclosed herein relates to a kind of method assessing the underground risk of landwaste re-injection operation, and described method comprises: the pressure signature obtaining a time period; Explain that described pressure signature is to determine the fracture behaviour of described rock stratum; Characterize the risk relevant to the fracture behaviour of determined described rock stratum; And implement solution based on characterized risk.。
By following description and unsettled claim, other aspects of the present invention and advantage will be apparent.
Accompanying drawing explanation
Fig. 1 illustrates the explanation of pressure signature and the method for anomalous identification.
Fig. 2 carries out the normality pressure signature of CRI operation immediately after closing well is shown.
Fig. 3 illustrates the pressure signature representing well bore storage pressure decline behavior.
Fig. 4 illustrates the pressure signature representing crackle storage pressure decline behavior.
Fig. 5 illustrates the pressure signature representing falling pressure bounce-back.
Fig. 6 illustrates the logarithmic plot representing the pressure signature that covering layer injects.
Detailed description of the invention
On the one hand, the embodiment disclosed herein relates to the pressure behavior explaining CRI operation.On the other hand, the embodiment disclosed herein relates to the potential risks and impact evaluating and cause underground well system and surrounding rock stratum.
Mud batch processing (that is, will meet the requirements of mud to be injected in process rock stratum, and then wait for a period of time after the implantation) allows crackle mechanically to close to a certain extent, eliminates the gathering of pressure in process rock stratum.But the pressure usually in process rock stratum increases due to the existence (that is, being present in the solid of well drilling detritus mud) of the solid of injection.
The parameter area that the mud that will be injected into should remain on calculating is interior with the chance reducing crackle blocking.In order to monitor mud, usually check that rheological parameter (rheological parameter) is to guarantee that mud has predetermined feature with regular principle.Such as, some systems are incorporated to the continuous measurement to mud viscosity and density before injection.
Must avoid abandoning harmful discarded object to environment, and must guarantee that the maintenance of discarded object or sealing meet strict statutory regulation.The important accommodation considered in during operating process or sealing factor comprise as follows: the position of the discarded object of injection and the mechanism of storage; Inject the capacity of well bore or annulus; Continue in current region to inject or continue in different regions to inject; Whether should bore another process well; Suitable discarded object is held or seals the operating parameter needed for necessity; And to the Mud Property parameter of the operation of solid suspension necessity in slurry transportation.
The modeling of CRI operation and the prediction of process discarded object degree are conducive to solving these and hold or sealing factor, and are conducive to the discarded object safety guaranteeing to process and legal accommodation or sealing.The model and forecast of fracture is also conducive to the CRI operation studying impact drilling well in the future, and example is well spacing as required, and rock pressure increases, etc.Storage mechanism in thorough understanding CRI operation is crucial for the possible range meeting the requirements of mud of prediction injection and the process capacity of prediction Injection Well.As adopted as in this, storage mechanism can refer to mud and be stored in model in rock stratum or method, comprises, and such as, injects the method for rock stratum, injects the method for crackle, crack growth, and the change of geometry of crack.
Once calculate closing well (shut-in) time needed for crack closure by fracture stimulation, next inject in batches and already present crackle may be caused again to ftracture, and the branch crack away from well bore near zone of secondary may be produced.This situation is by local stress, decided by the change and rock characteristic of injecting the hole pressure caused before.The position of branch crack and orientation also depend on the anisotropy of stress.Such as, if there is strong stress anisotropy, so crackle closely interval, but, if there is no stress anisotropy, then crackle wide-scale distribution.In injection process, how these crackles distribute and shape and scope how to change may be the key factor determining the process capacity processing well.
Usually, instant or real-time result can not be provided to the modeling of CRI operation and fracturation during CRI operation with simulation.In addition, the reason of fracturation behavior is not disclosed to the modeling of CRI operation and simulation.But the embodiment disclosed herein provides the method for the common pressure signature that a kind of observation, identification and explanation observe during CRI operation.In addition, the embodiment disclosed herein can provide a kind of method for designing to respond fracturation behavior during CRI operation.
In order to improve safety in CRI operation, can monitor continuously at the pressure-responsive injected and after closing well during pressure drop.The injection pressure be combined with depths Pressure Analysis of easy enforcement monitor can assisted diagnosis at the fracture behaviour aspirated and during closing well period, and contribute to estimating crucial crackle and formation parameters.In addition, continuous print Cracks Diagnosis can help to follow the trail of the long-term development and change of mechanical parameter in such as crack length, width and direction, and helps assessment by injecting the entire effect that with the rock stratum of surrounding cause of discarded object to process.
The primary goal of CRI is, by utilizing the trouble-free subsurface processes injecting acquisition Environmental security and drilling wastes of interval in batches.Therefore, as the identification of underground risk and an effective instrument of sign, the importance of Pressure Analysis is primary.The deep explanation of various pressure signatures repeatedly observed in circulation injection period may be used for the character disclosing and understand underground risk, characterizes possible reason, and assesses the future influence to underground system all sidedly.Suitably contribute to ensureing continuous print CRI operation with the explanation of pressure signature timely, extend the life-span of Injection Well, and maximize the process capacity of well.On the contrary, lack underground discarded object injection experiments and ignore obvious pressure signature unpredictable injection may be caused potentially to lose, this can increase the expense of again filling well or cause extra Injection Well drilling well.
Introduce the method explaining pressure signature below.Introduce below and be, the injection period of the various CRI engineering explanation of five kinds of pressure signatures the most general often observing and recognize in the whole world.The use that pressure signature is explained can provide better explanation for the imperfect pressure behavior of observation in CRI operation, potential risks and the impact on underground system can be estimated, and a solution or behavior can be provided based on the fixed fracture behaviour of rock stratum.
explain the method for pressure signature
Pressure signature from CRI operation can be explained to understand better and solve the imperfect pressure behavior observed in CRI operation.In addition, operator can estimate to operate the potential risk that causes and the impact on underground system by CRI.In one embodiment, pressure signature can comprise the curve of the multiple pressure measuring values recorded in one period of expression.The curve of this expression pressure signature illustrates in figs. 2-6.In another embodiment, pressure signature can be included in one period record and think shown in case form multiple pressure measuring values.Any those skilled in the art can recognize, pressure signature can comprise any known form of expression for representing the multiple pressure measuring values recorded within one period.
With reference to Fig. 1, in one embodiment, the pressure signature of one section of pre-selected time section in CRI operation can be determined, as shown in 120.Pressure signature is determined by any device of the prior art, and can obtain continuously with the time interval of change or in CRI operation after such as injection, closing well, during crack closure.
Then, explained to the pressure signature obtained is to determine the fracture behaviour of rock stratum each time period, as indicated at 122.In an embodiment, as described below, pressure signature can contrast with the pressure signature being identified as underground condition or the fracture behaviour representing rock stratum.Such as, the pressure signature obtained immediately after closing well can comprise the substantially straight line on pressure drop line.By the pressure signature of acquisition being compared with the pressure signature identified, operator can determine that fluid that pressure drop that well bore is stored shows between well bore with crackle is communicated with and be limited (carrying out detailed discussion referring to Fig. 3).
Based on the fracture behaviour explained by pressure signature 122 or underground behavior, solution 124 can be determined and implement 126 subsequently.Such as, if operator determines to be communicated with restriction between well bore with rock stratum, seawater can be injected to down-hole to prevent solids of sedimentation and/or to alleviate the stress of rock stratum, reduce thus or eliminate to be communicated with restriction.
In an embodiment, the underground risk relevant to fracture behaviour can represent with the scope of risk from low to high or characterize with the digital scope of the scope from low to high representing risk.Such as, in one embodiment, can pressure signature be explained, and determine the fracture behaviour of rock stratum.So, operator can sort out or characterize the risk of this fracture behaviour.Such as, if operator determines that crackle comprises horizontal component, operator can assess the risk of the well track cross of this crackle horizontal component and design.In this example, this Cracking behavior can be characterized by excessive risk by operator, because it may cause the drilling well failure of planned well.In other embodiments, pressure signature can be interpreted as the pressure drop representing normality (normal).Similarly, this Cracking behavior can be described as low-risk by operator.Therefore, the solution determined based on fracturation behavior can comprise holds fire or continues CRI operation.In other embodiments, the geometry that relevant to fracture behaviour underground risk can comprise well process capacity, the pressure change caused due to fracture behaviour of expection and the crackle of expection determining such as to be correlated with fracture behaviour changes.
the pressure drop of normality
The pressure (or pressure drop of routine) of normality is often observed during after closing well.Fig. 2 represents the pressure signature of the example representing normality pressure drop.Normality pressure is determined by the moment reaction of crack closure and rock stratum, and indicates (or unrestricted) open between crackle with well bore to be communicated with.Usually, falling period under stress distinguishes two different time periods: crack closure time period and transition formation time section.
Cracking behavior during the crack closure time period is controlled by fluid loss characteristic (that is, being lost to the fluid volume of rock stratum from crackle) and material balance relation.Pressure drop reflection crack length change during the crack closure time period and height change.Crack penetration increases at first, until fall back back eventually to well bore.Initial crack growth is generally because the redistribution from the large-scale crackle near well bore to crack tip region of the mud capacity of storage causes.Meanwhile, because pressure in crackle reduces (that is, net pressure), highly can fall after rise from any higher stress obstacle.By observing the shape of the pressure decline curves of pressure signature, the crackle height rising to higher stress obstacle (e.g., accommodation or sealing area) can be determined.Such as, to the instruction of recessed pressure drop characteristic pattern, one represents that the growth of crackle height does not reach higher stress cracking and holds or sealing area.On the contrary, the pressure drop characteristic pattern raised up represents a large amount of crackle height growing into higher stress obstacle region.
According to disclosed the present embodiment, underground situation can be determined by this pressure drop characteristic pattern.Such as, the pressure drop characteristic pattern raised up may mean, the fluid in crackle is from higher stress region (according to highly falling after rise) redistribution to main crackle main body.Usually, when net pressure becomes about 0.4 times that equals stress difference between injection zone and higher stress obstacle region, there is fluid in crackle from higher stress region to the redistribution of main crackle main body.By utilizing special time G-function, usually used as G value figure, can estimating of fluid efficiency and fluid leakage coefficient (for example, see, US Patent No. 6076046, inventor Vasudevan, at this by reference to quoting) from pressure drop characteristic pattern.But what the application of G-slope was seen in the explanation of conventional oil well test data with those equally has uncertainty.
Pressure drop during transition formation time section, or the pressure after crack closure, relate to and inject rock stratum response.During transition formation time section, pressure-responsive becomes the less mechanical response depending on open crackle, and more depends on the instantaneous pressure response in injection rock stratum.The feature of transition formation time section pressure drop first (if not all) is decided by the response being subject to the injection rock stratum that fluid leakage loss process (fluid migration is to fracture face) is disturbed.During this transition formation time section, first reservoir may show the linear flow of rock stratum, is then transient performance, and is finally long-term plan radial direction (pseudo-radial) flowing.(namely pressure drop during transition formation time section provides is tested by standard oil well, transfer rate and rock pressure) information determined traditionally, and completing a series of crackle Pressure Analysis, it provides the data needed for one group of complete unique sign being developed a kind of impact or result by fracture process.
Usually, the normality pressure signature of CRI operation represent underground system without any potential risk, and safe pressure signature can be counted as.Normal pressure signature can be used to assess the Cracking behavior in crack closure process, and for assessment of main crackle and formation parameters.Therefore, according to current disclosed embodiment, and as in figure 2, the pressure signature of the expression normality pressure drop during CRI operation can indicate operator, and the Cracking behavior of rock stratum does not imply the risk of underground system.So operator can continue CRI operation and need not take further action.
the pressure drop of well bore storage
Fig. 3 carries out the pressure signature of CRI operation immediately after representing closing well.Well bore storage pressure decline characteristic pattern represents the restriction between well bore and rock stratum.This restriction may be caused by the sealing such as brought by the viscous liquid reduced from previously injection or solid and precipitate between well bore and rock stratum.Also the machinery restriction accidentally may introduced at decanting point by such as cement causes this restriction.The response of well bore storage pressure can also be the result of fluid compression or expansion in a sealed volume.Rock stratum sealing stops the sufficient fluid between crackle and well bore to be communicated with, and causes the sealed volume in well bore.As shown in Figure 3, duration of well bore storage pressure section fall time depends on the compressible degree of artificial restriction and wellbore fluid, and can clearly characterize with the straightway occurred immediately on pressure drop line after being positioned at closing well, as illustrated at 302.No longer represent that crackle responds at the pressure drop of this time durations, and Crack Parameters can not be determined.
In many examples, the caution signal of the restriction that the well bore storage pressure field character representation shown immediately after closing well is introduced artificially at decanting point place.Owing to injecting the possible sealing at interval, the high risk of the well blocking that the well bore storage pressure behavior representation observed immediately after closing well is potential.When there is particle precipitation during injecting the suspension time period, the risk of potential soil-well jam increases the weight of.Consider that in CRI operation, soil-well jam causes the most serious fault, the partially sealed basic reason at any well bore storage pressure behavior observed immediately after closing well and injection interval must be monitored nearly, evaluated and is studied up hill and dale.
Still with reference to Fig. 3, there is shown in CRI scheme annulus injection period, while the shell with cementing 95/8 inch, the well bore storage pressure field feature observed immediately after closing well.In this example, actual level is than the height of initial design.As a result, cement bridge joint bore hole injects the part at interval, and introduces artificial restriction at decanting point.This is reflected by well bore storage pressure behavior (that is, the straight line portioies shown in 302) after closing well immediately in pressure signature, and by cement evaluation record, (log confirms subsequently.
Therefore, according to embodiment of the present disclosure, similar with Fig. 3, the pressure signature that represent closing well during CRI operation after, well bore storage pressure declines can indicate operator, and the fluid between well bore with crackle is communicated with and is limited.Therefore, in one embodiment, operator can implement seawater and injects to stop solids of sedimentation and/or with the stress discharging rock stratum.Alternatively, acid can pump into down-hole and limits to remove mechanicalness and recover the normal exchange between well bore and crackle.On the whole, such pressure signature as shown in Figure 3 represents the excessive risk of well or crackle blocking; Therefore, need monitor force field feature nearly, and take rapidly correct measure.
crackle storage pressure declines
With reference now to representing the pressure signature that crackle storage pressure declines shown in Fig. 4, figure.Pressure in during crackle storage pressure field feature generally shows as the time period after crack closure and the linear relationship between the time (that is, on pressure drop line shown in 404 straight line portion).Usually, the decline of crackle storage pressure is caused by the pressure kick after closing in the crack edge be limited or seal or vibration, as indicated at 406.By the fracture face formed in previous injection filter cake (filter cake) (e.g., residual polymer and solid particle) or cause crack edge to seal to the damage of fracture face.When flow losses causes crack width not enough, or when dehydration causes solid mud at crack tip bridge joint, (namely similar crackle restriction or sealing can also be observed in TSOP fracturing (tip screen-out (TSO)) period, when the gravel of high concentration or proppant (proppant) arrive crack tip, and interrupt further crack growth).
Assuming that the impact of well bore reserves on whole storage characteristic curve is less, during crackle period of storage section, pressure behavior is arranged by the fluid reserves in crackle.Crackle storage pressure is mainly due to can transmission of pressure and have the fluid compression of the crackle volume of higher infiltrative sealing or expansion relative to injecting rock stratum and occur effectively at crackle.Usually mechanically after landwaste solid, observe crackle storage pressure at crackle, therefore, allow fluid and pressure to redistribute in crackle.The factor affecting the crackle storage duration can comprise crackle and the permeability injected between rock stratum and pressure gap, and the seriousness of the harm produced at fracture face.
According to current disclosed embodiment, similar with Fig. 4, during CRI operation, represent that the pressure signature that crackle storage pressure declines can indicate operator, crack fracture face may be damaged, thus causes crackle to close.Therefore, in one embodiment, the fluid leaks that operator can use G-functional digraph to reappraise from crackle to rock stratum, and close by implementing extra fracture stimulations assessment crackle with the fluid leaks upgraded and main Crack Parameters (e.g., crackle confining pressure).
falling pressure rebounds
Referring now to representing the pressure signature that falling pressure rebounds shown in Fig. 5, figure.In the illustrated embodiment, interrupt when injection or suspend a rapid lapse of time, having observed the bounce-back of surface pressing during the pressure drop after closing well, as indicated at 508.Meanwhile, during CRI operation, the drilling well in Injection Well or activity in production may increase the amplitude of pressure bounce.Pressure drop drops to below crackle confining pressure at first, and continuous decrease is until wellbore fluid starts to heat up, and therefore affects the fluid pressure in well bore.Due to the heat produced between drilling well and/or productive life, wellbore fluid may heat up.When the temperature of wellbore fluid raises, hydrostatic pressure head (hydrostatic head) reduces, and causes surface pressing to increase (that is, pressure bounce effect) thus.
In the amplitude of the pressure increase between debounce periods and well bore, the rising of fluid temperature (F.T.) is proportional.Although pressure increases between debounce periods, because thermoelasticity is on the impact of rock stratum, crackle can not be restarted (re-initiated).That is, the variations in temperature of well bore changes stress state, particularly changes the stress state of well bore near zone.Typically, during stopping, heat up the horizontal stress component causing adding in rock stratum, and heat up in the rock stratum of well bore near zone improves normality pressure simultaneously.Therefore, wellbore fluid heats up and needs can be caused in order to overcome thermal stress additional in well bore near zone to start the higher critical pressure of crackle.
First relate to injection pressure higher on the surface to the excessive wellbore fluid relevant risk that heats up, and can not inject in the surface pressing extreme value preset.Like this, in an embodiment, the intercourse extended, inject by maintaining regular seawater, the wellbore fluid of effective cooling static state, can reduce the thermoelastic stress component near well bore.As a result, after break period section, need less pressure to start crackle, and surface imp lantation pressure can remain on below maximum extreme value.
supratectal injection
With reference now to Fig. 6, represent that the pressure signature that covering layer injects illustrates in logarithmic coordinates.As used herein, covering layer refers to the rock stratum or placer that cover interested subterranean zone or position.If injection pressure is less than covering layer stress, crackle can only be propagated along vertical plane.But carry out injecting or carry out in the rock stratum that earth crust structure enlivens thrust fault environment the situation injected under the condition of depth as shallow, covering layer pressure can be minimum main stress bar.Under the condition of this depth as shallow, crackle can be propagated in vertical plane and horizontal plane.This geometry is called as T-shape crackle, and occurs when injection pressure is a bit larger tham covering layer stress.
During injection pressure is a bit larger tham covering layer pressure, whether pressure-responsive provides to determine crack planes completely vertically or whether also comprise the diagnostic base of horizontal component.When crackle pressure is substantially constant and is approximately equal to or higher than the covering layer stress of rock stratum, create horizontal component (propagating in the horizontal direction), as shown in Figure 6.After injection pressure exceedes covering layer, because the horizontal component propagated is dominant, the infiltration of vertical component becomes no longer valid.
The crackle component of level increases the region that can be used for fluid loss, reduces hydraulic efficiency, and limits crack width.Fluid loss too much in horizontal component and limited crack width can cause screening too early in injection process or crackle blocking.Horizontal crackle can provide the overlay area with larger process capacity of expansion.But the risk that the intersection of locus due to the offset drilling to horizontal crackle and design is relevant, this horizontal crackle may need at large to assess.The size of covering layer pressure can be estimated by density record, and compares with the size of the injection pressure of the part as Pressure Analysis.
According to disclosed the present embodiment, similar with Fig. 6, the pressure signature that the expression covering layer during CRI operation injects can be used for determining the geometry of rock stratum crackle.Operator can determine a solution, to reduce too much fluid loss and/or to increase crack width to stop sand fallout too early in injection process or crackle blocking.If pressure signature instruction crackle may comprise horizontal component, then operator such as can redesign the track of following well, crossing with the horizontal component of crackle to avoid.In addition, operator can make an explanation with the details of regular principle to pressure signature, to avoid too early sand fallout, particularly in the too early sand fallout of the near zone of well bore or the point of intersection between the vertical component and horizontal component of crackle.
Advantageously, the embodiment disclosed herein provides a kind of method determining the fracture behaviour of rock stratum in CRI operation.Further, the embodiment disclosed herein can provide that a kind of fracture behaviour in CRI operation or rock stratum and subsurface picture carry out optimized method to well process capacity by allowing operator to determine.In other embodiments disclosed herein, provide a kind of for implementing the method for solution based on the fracture behaviour determination a solution determined by making an explanation to pressure signature.
Advantageously, the embodiment disclosed herein can provide a kind of to operator and solve the method for nonideal pressure behavior in CRI operation, and a kind of CRI of estimation operates the method for potential risk and the impact brought underground system and rock stratum.
Although inventor has described limited embodiment, benefit from and of the present inventionly one skilled in the art will recognize that other embodiments of invention can not deviate from this invention disclosed scope.Therefore, scope of invention only should limit by the claim of being correlated with.
Claims (3)
1., in the method to the response of fracturation behavior during rock stratum re-injection landwaste, described method comprises step:
Determine the pressure signature of a time period;
Explain that the pressure signature of this time period is to determine the fracture behaviour of described rock stratum, explain that the step of described pressure signature comprises and determine that described pressure signature is by the one in the following group formed: normality pressure drop, well bore storage pressure decline, crackle storage pressure declines, falling pressure rebounds and covering layer injects;
The feature of the fracture behaviour solution of described rock stratum is determined in explanation based on pressure field signal; And
Feature based on the fracture behaviour of described rock stratum is injected seawater or continues described landwaste re-injection.
2. method according to claim 1, also comprises second pressure signature of the time period obtained after implementing described solution, and determines whether described solution affects described fracture behaviour.
3. method according to claim 1, also comprises the visual representation producing described pressure signature.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US97209207P | 2007-09-13 | 2007-09-13 | |
| US60/972,092 | 2007-09-13 |
Related Parent Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN200880107170A Division CN101849080A (en) | 2007-09-13 | 2008-09-03 | Working pressure field signatures to predict injects the unusual method of well |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN104265211A true CN104265211A (en) | 2015-01-07 |
Family
ID=40452407
Family Applications (2)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN200880107170A Pending CN101849080A (en) | 2007-09-13 | 2008-09-03 | Working pressure field signatures to predict injects the unusual method of well |
| CN201410356336.1A Pending CN104265211A (en) | 2007-09-13 | 2008-09-03 | Method Of Using Pressure Signatures To Predict Injection Well Anomalies |
Family Applications Before (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN200880107170A Pending CN101849080A (en) | 2007-09-13 | 2008-09-03 | Working pressure field signatures to predict injects the unusual method of well |
Country Status (12)
| Country | Link |
|---|---|
| US (1) | US20100314104A1 (en) |
| EP (1) | EP2198115B1 (en) |
| CN (2) | CN101849080A (en) |
| AR (1) | AR068426A1 (en) |
| AU (1) | AU2008299195B2 (en) |
| BR (1) | BRPI0816851A2 (en) |
| CA (1) | CA2699503C (en) |
| CO (1) | CO6270163A2 (en) |
| EA (1) | EA021727B1 (en) |
| MX (1) | MX343973B (en) |
| NO (1) | NO2198115T3 (en) |
| WO (1) | WO2009035884A1 (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112211622A (en) * | 2019-07-11 | 2021-01-12 | 中国石油天然气股份有限公司 | Method and device for dividing oil reservoir pressure field |
Families Citing this family (18)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2009105330A2 (en) * | 2008-02-22 | 2009-08-27 | M-I L.L.C. | Method of estimating well disposal capacity |
| US8047284B2 (en) * | 2009-02-27 | 2011-11-01 | Halliburton Energy Services, Inc. | Determining the use of stimulation treatments based on high process zone stress |
| WO2012178026A2 (en) * | 2011-06-24 | 2012-12-27 | Board Of Regents, The University Of Texas System | Method for determining spacing of hydraulic fractures in a rock formation |
| PL408174A1 (en) | 2011-07-11 | 2014-12-22 | Schlumberger Technology B.V. | System and method for carrying out the well stimulation operations |
| US20140231084A1 (en) * | 2011-11-09 | 2014-08-21 | Ramesh Varadaraj | Drill Cuttings Re-Injection |
| US10578766B2 (en) | 2013-08-05 | 2020-03-03 | Advantek International Corp. | Quantifying a reservoir volume and pump pressure limit |
| CA2937225C (en) | 2013-12-18 | 2024-02-13 | Conocophillips Company | Method for determining hydraulic fracture orientation and dimension |
| CA2953727C (en) | 2014-06-30 | 2021-02-23 | Advantek International Corporation | Slurrification and disposal of waste by pressure pumping into a subsurface formation |
| US10385670B2 (en) | 2014-10-28 | 2019-08-20 | Eog Resources, Inc. | Completions index analysis |
| US10385686B2 (en) * | 2014-10-28 | 2019-08-20 | Eog Resources, Inc. | Completions index analysis |
| WO2017039622A1 (en) * | 2015-08-31 | 2017-03-09 | Halliburton Energy Services Inc. | Integrated workflow for feasibility study of cuttings reinjection based on 3-d geomechanics analysis |
| CN106371989A (en) * | 2016-05-06 | 2017-02-01 | 北京中电华大电子设计有限责任公司 | Efficient and secure attack fault injection method adopting batch processing mode |
| GB2562752B (en) * | 2017-05-24 | 2021-11-24 | Geomec Eng Ltd | Improvements in or relating to injection wells |
| MX2019015184A (en) | 2017-06-16 | 2020-08-03 | Advantek Waste Man Services Llc | Optimizing waste slurry disposal in fractured injection operations. |
| CA3099730A1 (en) | 2018-05-09 | 2019-11-14 | Conocophillips Company | Measurement of poroelastic pressure response |
| CN108952700B (en) * | 2018-08-21 | 2022-03-25 | 西南石油大学 | Method for determining anisotropic stratum well wall fracture pressure |
| CA3160203A1 (en) * | 2019-11-21 | 2021-05-27 | Conocophillips Company | Well annulus pressure monitoring |
| US11790320B2 (en) * | 2020-06-25 | 2023-10-17 | Schlumberger Technology Corporation | Approaches to creating and evaluating multiple candidate well plans |
Family Cites Families (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5050674A (en) * | 1990-05-07 | 1991-09-24 | Halliburton Company | Method for determining fracture closure pressure and fracture volume of a subsurface formation |
| US6002063A (en) * | 1996-09-13 | 1999-12-14 | Terralog Technologies Inc. | Apparatus and method for subterranean injection of slurried wastes |
| US6076046A (en) | 1998-07-24 | 2000-06-13 | Schlumberger Technology Corporation | Post-closure analysis in hydraulic fracturing |
| US7440876B2 (en) * | 2004-03-11 | 2008-10-21 | M-I Llc | Method and apparatus for drilling waste disposal engineering and operations using a probabilistic approach |
| US8091625B2 (en) * | 2006-02-21 | 2012-01-10 | World Energy Systems Incorporated | Method for producing viscous hydrocarbon using steam and carbon dioxide |
| CA2823116A1 (en) * | 2010-12-30 | 2012-07-05 | Schlumberger Canada Limited | System and method for performing downhole stimulation operations |
-
2008
- 2008-09-03 EP EP08799094.1A patent/EP2198115B1/en active Active
- 2008-09-03 BR BRPI0816851 patent/BRPI0816851A2/en active Search and Examination
- 2008-09-03 CN CN200880107170A patent/CN101849080A/en active Pending
- 2008-09-03 WO PCT/US2008/075087 patent/WO2009035884A1/en active Application Filing
- 2008-09-03 NO NO08799094A patent/NO2198115T3/no unknown
- 2008-09-03 MX MX2010002779A patent/MX343973B/en active IP Right Grant
- 2008-09-03 EA EA201070362A patent/EA021727B1/en not_active IP Right Cessation
- 2008-09-03 AU AU2008299195A patent/AU2008299195B2/en not_active Ceased
- 2008-09-03 CN CN201410356336.1A patent/CN104265211A/en active Pending
- 2008-09-03 CA CA2699503A patent/CA2699503C/en active Active
- 2008-09-03 US US12/677,719 patent/US20100314104A1/en not_active Abandoned
- 2008-09-12 AR ARP080103969A patent/AR068426A1/en not_active Application Discontinuation
-
2010
- 2010-03-12 CO CO10029656A patent/CO6270163A2/en not_active Application Discontinuation
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112211622A (en) * | 2019-07-11 | 2021-01-12 | 中国石油天然气股份有限公司 | Method and device for dividing oil reservoir pressure field |
| CN112211622B (en) * | 2019-07-11 | 2023-02-07 | 中国石油天然气股份有限公司 | Method and device for dividing oil reservoir pressure field |
Also Published As
| Publication number | Publication date |
|---|---|
| MX2010002779A (en) | 2010-04-07 |
| CO6270163A2 (en) | 2011-04-20 |
| EP2198115B1 (en) | 2017-08-02 |
| AU2008299195A1 (en) | 2009-03-19 |
| EP2198115A1 (en) | 2010-06-23 |
| EP2198115A4 (en) | 2015-12-02 |
| CA2699503C (en) | 2015-05-05 |
| CN101849080A (en) | 2010-09-29 |
| CA2699503A1 (en) | 2009-03-19 |
| EA201070362A1 (en) | 2010-10-29 |
| EA021727B1 (en) | 2015-08-31 |
| US20100314104A1 (en) | 2010-12-16 |
| AR068426A1 (en) | 2009-11-18 |
| BRPI0816851A2 (en) | 2015-03-17 |
| WO2009035884A1 (en) | 2009-03-19 |
| MX343973B (en) | 2016-11-30 |
| AU2008299195B2 (en) | 2012-08-23 |
| NO2198115T3 (en) | 2017-12-30 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN104265211A (en) | Method Of Using Pressure Signatures To Predict Injection Well Anomalies | |
| US8899349B2 (en) | Methods for determining formation strength of a wellbore | |
| US9175555B2 (en) | Fluid injection completion techniques | |
| AU2018285940B2 (en) | Optimizing waste slurry disposal in fractured injection operations | |
| CN110678626A (en) | Improvements in or relating to injection wells | |
| EP3821107A1 (en) | Systems and methods to identify and inhibit spider web borehole failure in hydrocarbon wells | |
| CN109899050A (en) | Form the bed gas reservoir fracturing process of complex fracture network | |
| Aborisade | Practical approach to effective sand prediction, control and management | |
| Mehtar et al. | Feed to execution: first successful hydraulic fracture cuttings re-injection process offshore Abu Dhabi | |
| Oyeneyin | Fundamental Principles of Management of Reservoirs with Sanding Problems | |
| Dobkins | Procedures, Results, and Benefits of Detailed Fracture Treatment Analysis | |
| Bin Marta et al. | Diagnosing and Controlling Excessive Water Production: State-of-the-Art Review | |
| Ruslan et al. | Integrated approach to sand management in matured field operations | |
| Vatsa et al. | Fracture Height Containment in the Stimulation of Oriskany Formation | |
| Gumarov et al. | Monitoring pioneer waste injection projects in caspian sea: challenges, lessons learned, findings and recent advancements | |
| US11753923B2 (en) | Using pre-fracturing hydraulic conductivity measurements to avoid fracture treatment problems | |
| Dib | ANALYSIS AND MANAGEMENT OF THE DRILLING ACTIVITY | |
| Bagci | Fracture modeling for cap rock integrity and completion evaluation in produced water re-injection wells | |
| DICKSON | Mechanistic Models for Predicting Sand Production: A Case Study of Niger Delta Wells | |
| Adams | A comprehensive review of wellbore breathing | |
| Udebhulu | Mechanistic Models for Predicting Sand Production: A Case Study of Niger Delta Wells | |
| Kharrat et al. | Practical Improved Hydrocarbon Recovery | |
| Al-Ameri | Suggested Workflow for the Tests Analyses of Hydraulically Fractured Well in Unconventional Reservoirs | |
| Abou-Sayed et al. | A Geomechanics Updates on Alaska's GNI Project: Monitoring, Assessment, Validation and Assurance for the World Largest Drill Cuttings Injection Project | |
| RE-INJECTION | PETROLEUM AND MINING ENGINEERING |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| C06 | Publication | ||
| PB01 | Publication | ||
| C10 | Entry into substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| RJ01 | Rejection of invention patent application after publication |
Application publication date: 20150107 |
|
| RJ01 | Rejection of invention patent application after publication |