WO1992006391A1 - Method for maeasuring propped fracture height using acoustic logs - Google Patents
Method for maeasuring propped fracture height using acoustic logs Download PDFInfo
- Publication number
- WO1992006391A1 WO1992006391A1 PCT/US1991/006472 US9106472W WO9206391A1 WO 1992006391 A1 WO1992006391 A1 WO 1992006391A1 US 9106472 W US9106472 W US 9106472W WO 9206391 A1 WO9206391 A1 WO 9206391A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- formation
- fracture
- compressional
- fracturing
- shear
- Prior art date
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Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/40—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
- G01V1/44—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators and receivers in the same well
Definitions
- the present invention relates to a method for measuring propped fracture height using acoustic logs.
- Logging devices have been used for this purpose which normally comprise a sound source (transmitter) and one or more receivers disposed at Pre-selected distances from the sound source.
- US-A-4,843,598 there is disclosed a method to determine the porosity of a formation surrounding a cased well from a shear wave log of the formation. Shear wave velocity determined fram the log and formation velocity is identified from a predetermined correlation between core-derived porosity for the type of formation traversed by the cased well and shear wave velocity.
- a method of acoustic well logging for identifying formation fracture intervals behind a cased well is disclosed in US-A-4,899,398.
- an acoustic logging tool having an asymmetric acoustic energy transducer was used to transverse a fluid-filled cased well.
- Pressure waves are created in the well fluid by transducer-generated asymmetric tube waves in the well casing.
- At least one spaced-apart transducer received those asymmetric tube waves after they had travelled directly to the receiver through the well casing. Changes in tube wave amplitude as detected by the receiver were used to identify the azimuth and height of a fracture interval in the formation behind the well casing.
- None of the above methods are directed toward the vise of compressional or shear waves to determine the height of a propped fracture as well as to determine the width of the propped fracture.
- a fluid-filled cased well is
- a well-logging tool containing an acoustic energy producer for producing compressional or shear waves or a combination thereof in the fill-fluid.
- the logging tool travels down the borehole it transmits acoustic energy out into the formation. This transmission of acoustic energy is allowed to pulse the formation at a plurality of locations in said borehole
- Produced acoustic energy is detected at each location where said energy has been produced by a pair of spaced-apart acoustic receivers.
- the detected energy is measured as a function of a velocity of the detected compressional and shear waves which were received by said receivers for each location.
- the formation is fractured hydraulically with a frac fluid having proppants therein which creates a propped fracture. Hydraulic fracture pressure is released on the formation. After propping the fracture, the logging tool is placed within and traverses said wellbore. Thereafter, acoustic energy is transmitted so as to pulse the formation adjacent to the borehole at the plurality of locations so as to produce acoustic energy. The acoustic energy is detected at each of the
- in-situ stress measurements are made at each of said locations using the velocities of compressional and shear waves which were previously detected after fracturing.
- the in-situ stresses relative to the velocities of the compressional and shear waves which were detected before fracturing are correlated with those obtained subsequent to fracturing the formation.
- Differences obtained between the in-situ stress measurements at each of said locations before and after fracturing the formation are used to predict the height of the propped fracture. Any difference between the stresses before and after fracturing is determined to be proportional to a width of an average proppant wedge which difference extends over the propped height of the fracture only.
- the present invention provides a method of logging a cased and/or uncased well to detect the height of a
- Figure 1 illustrates an acoustic well logging system employed in carrying out a shear or compressional wave velocity logging method of the present invention
- Figure 2 is a schematic representation of a propped fracture formed within a formation.
- the present invention is directed to a method for acoustic logging wherein the height of a propped fracture is determined along with its width.
- the method uses a direct generation of shear waves and compressional waves in order to obtain a correlation between shear wave and compressional wave travel times to predict formation in-situ stresses.
- an acoustic logging system is illustrated that produces shear motion directly in a subsurface reservoir without depending on mode conversion of compressional waves.
- the logging system includes an elongated tool 10 which is suspended from a cable 11 within cased well 12 which traverses a subsurface reservoir.
- Reservoir 14 may be a suspected oil or gas bearing formation which is to be
- Logging tool 10 comprises an acoustic transmitter 17 and acoustic receivers 19 and 20. Signals from logging tool 10 are
- the utilization system is illustrated as coitprising an uphole analysis and control circuit 22 along with recorder 24 in order that the output from circuit 22 may be correlated with depth.
- Transmitter 17 and preferably also receivers 19 and 20 are asymmetric acoustic wave generators of the type that produce shear or compressional waves in the formation surrounding well 12.
- a shear wave is a wave in which the motion, or direction of displacement, of particles within a medium in which the wave travels, is perpendicular to the direction of propagation of the wave.
- Such a shear wave is directly generated in the formation when a pressure wave within fluid 16 created by transmitter 17 strikes cased well 12.
- the casing of well 12 includes well pipe 26 bonded to formation 14 with cement 27. Such shear wave generation does not, therefore, depend on mode conversion of compressional waves.
- Transmitter 17 is an asymmetric acoustic energy source such as, for example, the bender-type transducer described in US-A-4, 516,228 and US-A-4,649,525.
- the transducer may suitably be a single piezoelectric element.
- the single piezoelectric element or a pair of piezoelectric plates may be mounted, respectively, on a single or opposite side of an inert element which is properly hinged for the flexural motion.
- Other suitable transducers that may be successfully employed may be of the conventional magnetostrictive or electro-magnetic type.
- a borehole logging tool 10 is placed into wellbore 12 within formation 14.
- the logging tool 10 is moved up and down the wellbore while a transmitting means within said tool pulsates the wellbore at a plurality of locations via produced acoustic energy.
- the acoustic energy which is produced is detected at a plurality of spaced-apart locations by receivers 19 and 20.
- the velocity of the compressional and/or shear waves are detected by receivers 19 and 20 and the amount of energy is measured for each of said locations.
- the amplitude and speed at which the waves move through the formation are recorded on recorder 24.
- in-situ stress calculations are made of stresses at each of the locations where the shear wave energy was measured when produced from said logging tools.
- In-situ stresses can be calculated using rock mechanics as is Known by those skilled in the art. However, if it is desired to make in-situ stress measurements of rock masses, these measurements can be made by methods disclosed in US-A-4,491,022 and US-A-4,673,890.
- a device is suspended within a borehole and is used to make in-situ stress measurements. After making the in-situ stress measurements, the stress measurements are then correlated with the velocity of the shear and compressional waves which were detected at the plurality of locations in the borehole as mentioned previously.
- the formation is fractured hydraulically by placing in wellbore 12 a hydraulic frac fluid with a proppant therein. Hydraulic fracturing methods and proppants for utilization within a propped fracture are known to those skilled in the art and thus will not be discussed further here.
- the borehole logging tool is again lowered into the formation and the means for transmitting acoustic energy is again used along the same plurality of locations within said borehole.
- Acoustic energy which is transmitted into the formation is pulsed at the plurality of locations and produces acoustic energy in the form of compressional or shear waves.
- the energy which is produced is detected at each of said plurality of locations by the pair of spaced-apart receivers 19 and 20.
- the velocity of the compressional and shear waves which is detected by receivers 19 and 20 for each of said locations is transmitted to the surface and recorded on recorder 24. After recording the velocity of the shear waves, energy resulting from said transmission is measured.
- in-situ stresses at each of the locations previously logged for compressional and shear velocities are again measured.
- the in-situ stresses are determined from rock mechanics theoretical methods. Once the velocity of the shear and compressional waves have been measured for each of the plurality of said locations after fracturing the formation, the measurements are correlated with in-situ stresses determined at the same locations for comparison with the velocity of the generated ccmpressional and shear waves.
- Fracture width 30 is also shown. As is anticipated, any difference in stress before and after fracturing the formation will be proportional to a width of an average proppant wedge which difference will extend over the propped hei ght only. Any increase in in-situ stresses is caused by the proppant wedge inside of created fracture 28. Compressional and shear wave velocities which have been obtained by the foregoing method are corrected for lithology and fluid saturation by utilization of Biot-Gassman equations. Fracture height 32 can also be determined by comparing a difference between shear to
- compressional ratio velocities before and after fracturing In order to better delineate the arrival of compressional and shear wave velocities before and after fracturing a polarized logging tool can be utilized. Should it be desired to do so, shear velocities before and after fracturing can also be used to determine the fracture height.
- the compressional and shear wave velocity ratios can be correlated and a cross-plot made thereof from core samples which have kncwn in-situ stresses.
- This invention is equally applicable to either cased or uncased wells. By subtracting pre-fracture in-situ stresses from post-fracture in-situ stresses, any resultant curves should represent a change in the in-situ stresses and indicate propped fracture height. Fracture mechanic analysis can be used to verify the fracture dimensions also.
Abstract
A method for determining a propped fracture's (28) height (32) and width (30) wherein acoustic logging devices are used in a borehole. Compressional and shear wave velocities obtained by transmitting acoustic energy through the borehole (12) and into the formation are made at a plurality of locations before and after fracturing the formation. In-situ stresses are determined at the plurality of locations before and after fracturing the formation from velocities of the compressional and shear waves which were detecte before and after fracturing the formation. Differences between in-situ stresses obtained at each of said locations before and after fracturing the formation are used to predict a height and width of a propped fracture.
Description
METHOD FOR MEASURING PROPPED FRACTURE
HEIGH T USING ACOUSTIC LOGS
The present invention relates to a method for measuring propped fracture height using acoustic logs.
It has been known to acoustically log open wellbores to determine the velocities of compressional ("P") waves and shear ("S") waves travelling through rock formations located in a wellbore region. Similarly, tube waves ("T") traveling along the wellbore interface can also be detected. Logging devices have been used for this purpose which normally comprise a sound source (transmitter) and one or more receivers disposed at Pre-selected distances from the sound source.
By timing the travel of compressional waves, shear waves and/or tube waves between the transmitter and each receiver, it is normally possible to determine the nature of surrounding rock formations including natural fracture identification. For descriptions of various logging techniques for collecting and analyzing conpressional waves, shear waves, tube waves and secondary wave data, refer to : US-A-3,333,238; US-A-3,356,177; US-A-3,362,011; US Reissue No. 24,466; US-A-4,383,308; and US-A-4,715,019; and to "The Correlation of Tube Wave Events With Open Fractures In Fluid-Filled Boreholes" by Huang and Hunter in Geological Survey of Canada, pgs. 336-376, 1981.
In each of the foregoing references, acoustic waves are generated in the formation in response to an acoustic energy transmission from within an open wellbore. However, the teachings of such references are not applicable to the
identification of induced propped fractures in formations which are traversed by a well casing, i.e., well pipe cement bonded to the formation.
In US-A-4,843,598 there is disclosed a method to determine the porosity of a formation surrounding a cased well from a shear wave log of the formation. Shear wave velocity determined fram the log and formation velocity is identified from a predetermined correlation between core-derived porosity for the type of formation traversed by the cased well and shear wave velocity.
A method of acoustic well logging for identifying formation fracture intervals behind a cased well is disclosed in US-A-4,899,398. In this method, an acoustic logging tool having an asymmetric acoustic energy transducer was used to transverse a fluid-filled cased well. Pressure waves are created in the well fluid by transducer-generated asymmetric tube waves in the well casing. At least one spaced-apart transducer received those asymmetric tube waves after they had travelled directly to the receiver through the well casing. Changes in tube wave amplitude as detected by the receiver were used to identify the azimuth and height of a fracture interval in the formation behind the well casing.
None of the above methods are directed toward the vise of compressional or shear waves to determine the height of a propped fracture as well as to determine the width of the propped fracture.
In accordance with the present invention, there is provided a method of acoustic well logging for detecting hydraulically induced intervals of a propped fracture
existing behind a cased or uncased well. Additionally, the method can be used to also determine the width of the propped fracture. Specifically, a fluid-filled cased well is
traversed with a well-logging tool containing an acoustic energy producer for producing compressional or shear waves or a combination thereof in the fill-fluid.
As the logging tool travels down the borehole it transmits acoustic energy out into the formation. This transmission of acoustic energy is allowed to pulse the formation at a plurality of locations in said borehole
thereby producing the acoustic energy. Produced acoustic energy is detected at each location where said energy has been produced by a pair of spaced-apart acoustic receivers.
Thereafter, the detected energy is measured as a function of a velocity of the detected compressional and shear waves which were received by said receivers for each location.
Subsequently, in-situ stresses are predicted at each of said locations using the velocities of the detected compressional and shear waves.
The formation is fractured hydraulically with a frac fluid having proppants therein which creates a propped fracture. Hydraulic fracture pressure is released on the formation. After propping the fracture, the logging tool is placed within and traverses said wellbore. Thereafter, acoustic energy is transmitted so as to pulse the formation adjacent to the borehole at the plurality of locations so as to produce acoustic energy. The acoustic energy is detected at each of the
locations by a pair of spaced-apart acoustic receivers. Then the energy is measured as a function of a velocity of
compressional and shear waves which were detected by said receiver for each location.
Next, in-situ stress measurements are made at each of said locations using the velocities of compressional and shear waves which were previously detected after fracturing. The in-situ stresses relative to the velocities of the compressional and shear waves which were detected before fracturing are correlated with those obtained subsequent to fracturing the formation. Differences obtained between the in-situ stress
measurements at each of said locations before and after fracturing the formation are used to predict the height of the propped fracture. Any difference between the stresses before and after fracturing is determined to be proportional to a width of an average proppant wedge which difference extends over the propped height of the fracture only.
The present invention provides a method of logging a cased and/or uncased well to detect the height of a
hydraulically induced propped fracture in a formation as well as the width of said fracture. This enables the drainage of a hydrocarbonaceous fluid αantaining formation or reservoir to be more readily predicted.
Reference is new made to the accompanying drawings, in which:
Figure 1 illustrates an acoustic well logging system employed in carrying out a shear or compressional wave velocity logging method of the present invention; and
Figure 2 is a schematic representation of a propped fracture formed within a formation.
The present invention is directed to a method for acoustic logging wherein the height of a propped fracture is determined along with its width. The method uses a direct generation of shear waves and compressional waves in order to obtain a correlation between shear wave and compressional wave travel times to predict formation in-situ stresses.
Referring now to Figure 1, an acoustic logging system is illustrated that produces shear motion directly in a subsurface reservoir without depending on mode conversion of compressional waves. The logging system includes an elongated tool 10 which is suspended from a cable 11 within cased well 12 which traverses a subsurface reservoir. Reservoir 14 may be a suspected oil or gas bearing formation which is to be
characterized in regard to in-situ stresses and fracture height determination. Well 12 is filled with a liquid 16. Logging tool 10 comprises an acoustic transmitter 17 and acoustic receivers 19 and 20. Signals from logging tool 10 are
transmitted uphole by conductors within cable 11 to any suitable utilization system at the surface. For example, the utilization system is illustrated as coitprising an uphole analysis and control circuit 22 along with recorder 24 in order that the output from circuit 22 may be correlated with depth.
Transmitter 17 and preferably also receivers 19 and 20 are asymmetric acoustic wave generators of the type that produce shear or compressional waves in the formation surrounding well 12. A shear wave is a wave in which the motion, or direction of displacement, of particles within a medium in which the wave travels, is perpendicular to the direction of propagation of the wave. Such a shear wave is directly generated in the formation when a pressure wave within fluid 16 created by transmitter 17 strikes cased well 12. The casing of well 12 includes well pipe 26 bonded to formation 14 with cement 27. Such shear wave generation does not, therefore, depend on mode conversion of compressional waves. Transmitter 17 is an asymmetric acoustic energy source such as, for example, the bender-type transducer described in US-A-4, 516,228 and US-A-4,649,525.
While such bender-type transducer is described in said patents as being a pair of piezoelectric plates bonded together
for dipole flexural motion, the transducer may suitably be a single piezoelectric element. Further, the single piezoelectric element or a pair of piezoelectric plates may be mounted, respectively, on a single or opposite side of an inert element which is properly hinged for the flexural motion. Other suitable transducers that may be successfully employed may be of the conventional magnetostrictive or electro-magnetic type.
A good discussion of a shear wave logging tool, shear wave transmission, and an application of shear wave methods in exploration, appears in US-A-4,843 ,598.
Although a shear wave logging tool has been mentioned above, other logging devices may be utilized. One such logging device is disclosed in US-A-4,383,308. This patent is directed to a method for acoustic well logging wherein shear and compressional waves were detected.
In the practice of this invention as shown in Figure 1, a borehole logging tool 10 is placed into wellbore 12 within formation 14. The logging tool 10 is moved up and down the wellbore while a transmitting means within said tool pulsates the wellbore at a plurality of locations via produced acoustic energy. The acoustic energy which is produced is detected at a plurality of spaced-apart locations by receivers 19 and 20.
Depending on the logging tool utilized, the velocity of the compressional and/or shear waves are detected by receivers 19 and 20 and the amount of energy is measured for each of said locations. Prior to measuring the velocity of the waves which have been generated in the formation, the amplitude and speed at which the waves move through the formation are recorded on recorder 24.
After measuring the velocity at which a shear wave or a compressional wave has moved through formation 14, in-situ stress calculations are made of stresses at each of the locations where the shear wave energy was measured when produced
from said logging tools. In-situ stresses can be calculated using rock mechanics as is Known by those skilled in the art. However, if it is desired to make in-situ stress measurements of rock masses, these measurements can be made by methods disclosed in US-A-4,491,022 and US-A-4,673,890. In each of these patents, a device is suspended within a borehole and is used to make in-situ stress measurements. After making the in-situ stress measurements, the stress measurements are then correlated with the velocity of the shear and compressional waves which were detected at the plurality of locations in the borehole as mentioned previously.
After obtaining a correlation between the velocity of the shear wave and compressional wave at each of the plurality of locations relative to in-situ stress measurements at each of said locations prior to fracturing the formation, thereafter the formation is fractured hydraulically by placing in wellbore 12 a hydraulic frac fluid with a proppant therein. Hydraulic fracturing methods and proppants for utilization within a propped fracture are known to those skilled in the art and thus will not be discussed further here.
A method for formation stimulation in horizontal well-bores using hydraulic fracturing is discussed in
US-A-4,938,286. Once the hydraulic fracture has been created it is necessary to determine the extent to which the fracture has propagated through the formation. This information is needed in order to determine hydrocarbonaceous fluid flow from the formation into the fracture which will be produced to the surface.
After the formation is fractured, the borehole logging tool is again lowered into the formation and the means for transmitting acoustic energy is again used along the same plurality of locations within said borehole. Acoustic energy
which is transmitted into the formation is pulsed at the plurality of locations and produces acoustic energy in the form of compressional or shear waves. The energy which is produced is detected at each of said plurality of locations by the pair of spaced-apart receivers 19 and 20. The velocity of the compressional and shear waves which is detected by receivers 19 and 20 for each of said locations is transmitted to the surface and recorded on recorder 24. After recording the velocity of the shear waves, energy resulting from said transmission is measured.
After making the measurements, in-situ stresses at each of the locations previously logged for compressional and shear velocities, are again measured. The in-situ stresses are determined from rock mechanics theoretical methods. Once the velocity of the shear and compressional waves have been measured for each of the plurality of said locations after fracturing the formation, the measurements are correlated with in-situ stresses determined at the same locations for comparison with the velocity of the generated ccmpressional and shear waves.
Afterwards, differences obtained between in-situ stresses at each of said plurality of locations before and after fracturing the formation are used to predict the height of the propped fracture.
As demonstrated in Figure 2, fracture 28 which emanates from wellbore 12 penetrates formation or reservoir 14. Fracture width 30 is also shown. As is anticipated, any difference in stress before and after fracturing the formation will be proportional to a width of an average proppant wedge which difference will extend over the propped hei ght only. Any increase in in-situ stresses is caused by the proppant wedge inside of created fracture 28. Compressional and shear wave velocities which have been obtained by the foregoing method are
corrected for lithology and fluid saturation by utilization of Biot-Gassman equations. Fracture height 32 can also be determined by comparing a difference between shear to
compressional ratio velocities before and after fracturing. In order to better delineate the arrival of compressional and shear wave velocities before and after fracturing a polarized logging tool can be utilized. Should it be desired to do so, shear velocities before and after fracturing can also be used to determine the fracture height.
In those situations where a borehole tool or theoretical rock mechanics methods are not desired to be utilized in determining in-situ stresses, the compressional and shear wave velocity ratios can be correlated and a cross-plot made thereof from core samples which have kncwn in-situ stresses. This invention is equally applicable to either cased or uncased wells. By subtracting pre-fracture in-situ stresses from post-fracture in-situ stresses, any resultant curves should represent a change in the in-situ stresses and indicate propped fracture height. Fracture mechanic analysis can be used to verify the fracture dimensions also.
Claims
1. A method for measuring a propped fracture height via an acoustic log which fracture emanates from a borehole within a formation comprising: a) traversing the formation surrounding said borehole with a logging tool having a means for transmitting acoustic energy; b) pulsing said transmitting means at a plurality of locations in said borehole to produce acoustic energy therein; c) detecting for each location said produced energy at a pair of spaced-apart acoustic receivers; d) measuring the energy as a function of a velocity of compressional and shear waves detected by said receivers for each location; e) determining in-situ stresses at each of said locations from the velocities of compressional and shear waves which were detected; f) fracturing hydraulically said formation with a frac fluid having proppants therein, thereby creating a propped fracture and thereafter releasing hydraulic fracture pressure on said formation; g) repeating steps a) through d) and determining in-situ stresses after fracturing at each of said locations as in step c); and h) using differences between in-situ stresses obtained at each of said locations before and after fracture formation to predict a height of the propped fracture.
2. A method according to claim 1 wherein a difference in stresses before and after fracturing is proportional to a width of an average proppant wedge which difference extends over the propped height only.
3. A method according to claim 1 wherein a long spaced
acoustic logging tool or a shear wave acoustic logging tool and combinations thereof are used.
4. A method according to claim 1 wherein an increase in the in-situ stresses is caused by proppant wedged inside the created fracture.
5. A method according to claim 1 wherein the compressional and shear wave velocities are corrected for lithology and fluid saturation by utilization of Biot-Gassman equations.
6. A method according to claim 1 wherein said borehole is either cased or uncased.
7. A method according to claim 1 wherein formation in-situ stresses are determined by correlating compressional and shear wave velocity ratios and a crossplot is formulated from core samples of known in situ stresses.
8. A method according to claim 1 wherein by comparing the shear velocities before and after fracturing, fracture height is determined.
9. A method according to claim 1 wherein fracture height is determined by comparing the difference between shear to compressional ratio velocities before and after fracturing.
10. A method according to claim 1 wherein a polarized
logging tool is used to better delineate the arrival of compressional and shear wave velocities before and after fracturing.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US59370790A | 1990-10-04 | 1990-10-04 | |
| US593,707 | 1990-10-04 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| WO1992006391A1 true WO1992006391A1 (en) | 1992-04-16 |
Family
ID=24375818
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| PCT/US1991/006472 WO1992006391A1 (en) | 1990-10-04 | 1991-09-09 | Method for maeasuring propped fracture height using acoustic logs |
Country Status (2)
| Country | Link |
|---|---|
| AU (1) | AU8719191A (en) |
| WO (1) | WO1992006391A1 (en) |
Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2014209786A1 (en) * | 2013-06-24 | 2014-12-31 | Baker Hughes Incorporated | Fracture evaluation through cased boreholes |
| WO2015026319A1 (en) * | 2013-08-19 | 2015-02-26 | Halliburton Energy Services, Inc. | Generating seismic pulses by compressive forces to map fractures |
| WO2016067108A1 (en) * | 2014-10-27 | 2016-05-06 | Cgg Services Sa | Predicting hydraulic fracture treatment effectiveness and productivity in oil and gas reservoirs |
| US10684384B2 (en) | 2017-05-24 | 2020-06-16 | Baker Hughes, A Ge Company, Llc | Systems and method for formation evaluation from borehole |
| CN112727423A (en) * | 2020-12-30 | 2021-04-30 | 中国海洋石油集团有限公司 | Method for finely evaluating hydraulic fracturing fracture height of offshore sandstone reservoir |
-
1991
- 1991-09-09 AU AU87191/91A patent/AU8719191A/en not_active Abandoned
- 1991-09-09 WO PCT/US1991/006472 patent/WO1992006391A1/en unknown
Non-Patent Citations (2)
| Title |
|---|
| AHMED, U., "Fracture Height Determination", JOURNAL OF PETROLEUM TECHNOLOGY, Vol. 40, 7, July 1988. * |
| SCHLUMBERGER ARRAY - SONIC SERVICE BROCHURE. * |
Cited By (11)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2014209786A1 (en) * | 2013-06-24 | 2014-12-31 | Baker Hughes Incorporated | Fracture evaluation through cased boreholes |
| US9670770B2 (en) | 2013-06-24 | 2017-06-06 | Baker Hughes Incorporated | Fracture evaluation through cased boreholes |
| WO2015026319A1 (en) * | 2013-08-19 | 2015-02-26 | Halliburton Energy Services, Inc. | Generating seismic pulses by compressive forces to map fractures |
| GB2532618A (en) * | 2013-08-19 | 2016-05-25 | Halliburton Energy Services Inc | Generating seismic pulses by compressive forces to map fractures |
| AU2013398369B2 (en) * | 2013-08-19 | 2017-06-08 | Halliburton Energy Services, Inc. | Generating seismic pulses by compressive forces to map fractures |
| US10215873B2 (en) | 2013-08-19 | 2019-02-26 | Hallliburton Energy Services, Inc. | Generating seismic pulses by compressive force to map fractures |
| WO2016067108A1 (en) * | 2014-10-27 | 2016-05-06 | Cgg Services Sa | Predicting hydraulic fracture treatment effectiveness and productivity in oil and gas reservoirs |
| US10802168B2 (en) | 2014-10-27 | 2020-10-13 | Cgg Services Sas | Predicting hydraulic fracture treatment effectiveness and productivity in oil and gas reservoirs |
| US10684384B2 (en) | 2017-05-24 | 2020-06-16 | Baker Hughes, A Ge Company, Llc | Systems and method for formation evaluation from borehole |
| CN112727423A (en) * | 2020-12-30 | 2021-04-30 | 中国海洋石油集团有限公司 | Method for finely evaluating hydraulic fracturing fracture height of offshore sandstone reservoir |
| CN112727423B (en) * | 2020-12-30 | 2022-11-18 | 中国海洋石油集团有限公司 | Method for finely evaluating hydraulic fracturing fracture height of offshore sandstone reservoir |
Also Published As
| Publication number | Publication date |
|---|---|
| AU8719191A (en) | 1992-04-28 |
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