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Brandon Sun - ONLINE EDITION
Poll shows Liberal lead in Brandon–Souris
People expected it would be close — but a new poll showing that the Brandon–Souris byelection race is within a few points has a surprising twist.
Global News reports that a poll conducted by Forum Research has Liberal candidate Rolf Dinsdale leading in Brandon–Souris, with 39 per cent support, ahead of Conservative candidate Larry Maguire, who trails with 35 per cent support.
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That's within the margin of error, which is considered to be plus or minus five percentage points.
The NDP and Green candidates were tied with 12 per cent support each.
"For a federal Liberal to be leading in Brandon‐Souris is a strange result indeed," Forum Research president Lorne Bozinoff told Global. "The Justin factor seems to be working right across the country."
The polling was conducted on Oct. 17–18, and was an interactive voice response telephone survey of randomly selected Canadians over the age of 18. Earlier this year, the company says that the technology was the most accurate in polling for the B.C. provincial election.
Byelections have been set for Nov. 25. Canadians will go to the ballot box in the ridings of Provencher, Bourassa and Toronto Centre, as well as Brandon–Souris. Forum Research says that their polls put the Liberal candidates head in all the ridings except Provencher.
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Posted by:JOHN FEFCHAK
October 23, 2013 at 10:33 AM
Are there two Larry Maguires in the Virden area now ?, as according to -days paper (23 Oct), One of the Maquires, is reported a saying it wasn't him who vented comments on this website.
Posted by:Doug17
October 22, 2013 at 11:10 AM
It's time to give a smarten up call to the Conservatives. The treatment of our veterans is disgraceful;the spending of $one billion on a new building for the intelligence agency;$190 million for temporary accomodations for the Senate;the Senate fiasco and cover up, etc. The list goes on and on.
Posted by:larrymaguireleg govmbca
October 21, 2013 at 8:45 PM
How come? Perhaps because some candidates know the rules, do their homework, meet the clearly set out requirements and are prepared to start at a common starting point....this is pretty basic! You move on the puck before its dropped you are waved out of the circle, you jump the gun at a 100 yd dash etc etc. At what point in time are people in highly responsible positions expected to be responsible for their actions when it comes to meeting the basic first steps in attempting to prove their capability to be worthy to fill these roles? I say the application process is a good place to start.
Posted by:George Hall
October 21, 2013 at 5:41 PM
I don't like the idea that we don't get to pick our own candidate and have to take Larry Maquire. Maybe Mr. Harper wants to make sure they have someone who will do exactly as he is told at all times.
Posted by:RCP
October 21, 2013 at 3:05 PM
I wonder how Rick Pauls would have done here. I will assume the Liberals #s are for the party and not the candidate in this situation.
Yes, too bad PC's pushed Larry in and pulled other candidates with great potential out.
Posted by:jeepster
October 21, 2013 at 12:52 PM
Who did they poll? The liberal sheep!
Posted by:JOHN FEFCHAK
October 21, 2013 at 11:04 AM
I am not surprised,considering the way that Larry Maquire was ushered into becoming the only candidate the Fed. Conservative would accept , leaving the other willing candidates outside, wondering ….HOW Come?
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Welcome to St. Mark's Episcopal Church!
We are an open community of believers on a journey to love Christ, love our neighbor, and serve the world. We hope that you will encounter God in our midst.
Please Join Us!
8 am ~ Worship (Rite 1)
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Wednesdays at 10 am ~ Worship in the Chapel (downstairs)
Thursdays at 6:30 pm ~ Healing Service in the Chapel (downstairs)
Fr. Sean has announced that he has accepted a call to another parish. Fr. Sean's last Sunday will be June 26. Check out the Transitions News Page for more information.


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This does not relate directly to my development project but I am curious none the less. Recently, after a lot of head-banging, I traced a build problem to an invalid entry in the System PATH variable. On my machine, it contains about 20 entries. I am guessing there has to be an easier way to verify the validity of each entry. Can anyone suggest a way to check this? Thanks for your time.
This code in a batch file (based on this answer) works for me:
Put the code into a text file, e.g.
When run, it should output something like:


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|Publication number
|Publication type
|Application number
|Publication date
|Nov 14, 2006
|Filing date
|Apr 14, 2004
|Priority date
|Apr 18, 2003
|Fee status
|Also published as
|Publication number
|Dean Willberg, Jean Desroches, Kamal Babour, Kais Gzara, Christian Besson
|Original Assignee
|Schlumberger Technology Corporation
|Export Citation
|BiBTeX, EndNote, RefMan
|Patent Citations (13), Non-Patent Citations (31), Referenced by (46), Classifications (11), Legal Events (3)
|External Links: USPTO, USPTO Assignment, Espacenet
This application claims the benefit of U.S. Provisional Patent Application No. 60/463,868, filed on Apr. 18, 2003.
This invention relates generally to the art of hydraulic fracturing in subterranean formations and more particularly to a method and means for assessing hydraulic fracture geometry during or after hydraulic fracturing.
Hydraulic fracturing is a primary tool for improving well productivity by placing or extending channels from the wellbore to the reservoir. This operation is essentially performed by hydraulically injecting a fracturing fluid into a wellbore penetrating a subterranean formation and forcing the fracturing fluid against the formation strata by pressure. The formation strata or rock is forced to crack, creating or enlarging one or more fractures. Proppant is placed in the fracture to prevent the fracture from closing and thus the fracture provides improved flow of the recoverable fluids, i.e. oil, gas or water.
The proppant is thus used to hold the walls of the fracture apart to create a conductive path to the wellbore after pumping has stopped. Placing the appropriate proppant at the appropriate concentration to form a suitable proppant pack is thus critical to the success of a hydraulic fracture treatment.
The geometry of the hydraulic fracture placed directly affects the efficiency of the process and the success of the operation. However, there are currently no direct methods of measuring the dimensions of a hydraulic fracture. The three methods currently used, pressure analysis, tiltmeter observational analysis, and microseismic monitoring of hydraulic fracture growth all require de-convolution of the acquired data for the fracture geometry to be inferred through the use of models—which is highly dependent on key assumptions—and often the results of these analyses verge on conjecture. All these methods use indirect measurements and are difficult to use except for post-job analysis rather than real-time evaluation and optimization of the hydraulic treatment. Moreover, these methods provide little information as to the actual shape of the propped fracture.
It is therefore an object of the present invention to provide a new approach to evaluating hydraulic fracture geometry.
The present invention is a method of assessing the geometry of a fracture using explosive, implosive or rapidly combustible particulate material added to the fracturing fluid and pumped into the fracture during the stimulation treatment. The particles are detonated or ignited during the treatment, subsequent to the treatment during closure, or after the treatment. The acoustic signal generated by these discharges is detected by geophones placed on the ground surface, in a nearby observation well, or in the well being treated. The technique is similar to that currently employed in microseismic detection—however in the current invention the signal is guaranteed to originate in the fracture.
The above and further objects, features and advantages of the present invention will be better understood by reference to the appended detailed description and to the drawings.
As illustrated in
Presently there are three techniques for determining the geometry of hydraulic fractures. The first, which is highly indirect, involves fitting the pressure transient obtained during the treatment. This technique is highly conjectural, since only two variables are known, pressure at the wellhead and rate, while the overall pressure response is a function of at least six different properties. The accuracy of this process is improved using bottom hole pressure gauges—an infrequent operation due to the expense, and technical difficulties.
A second more direct method uses tilt meters to measure changes in the inclination of the surface of the earth in the vicinity of the well, or of a nearby observation wellbore. This method involves a significant effort to de-convolute the signal. Variations, such as "ragged" frac growth in layered formations cannot be readily discerned by this method.
A third method involves the detection of microseismic events triggered by the fracturing treatment—either during growth or closure. Fracture growth, rock dislocations, and slippages along bedding planes or natural fractures give rise to seismic events. The acoustic signatures of these events are detected by strings of geophones mounted on the surface of the earth, in the well being fractured, or in a nearby observation wellbore.
The one major disadvantage of the microseismic method is that the sources of the acoustic signal can occur a significant distance away from the fracture itself. These events form a "swarm" around the actual fracture. The dispersed distribution of these events makes the de-convolution of the fracture's actual dimensions somewhat difficult. Furthermore, a hydraulic fracture does not necessarily give rise to microseismicity, so that the absence of events does not imply there is no fracture propagating in the "silent" layers.
According to the present invention, small explosive charges or implosive sources are pumped into the fracture during the treatment. When these charges ignite, or explode, they generate an acoustic or seismic signature guaranteed to have originated within the fracture. Since the source of these acoustic signatures is guaranteed to be within the fracture, de-convolution of the resulting seismic transients is greatly simplified, and the map generated by this process is more accurate than currently available with the microseismic process. Throughout this specification we use various terms for the event that creates the acoustic or seismic signal. These terms include detonation, explosion, implosion, ignition, combustion, exothermic reaction, and other forms of these words as appropriate such as explosive, detonator, combustible, etc.; it is to be understood that we will use the generic term "discharge" (and other forms of the word as appropriate) to represent any and all of these events. However, when we specifically discuss detonators and explosive matter together, it is to be understood that in that case we mean that the detonation of the detonator in turn causes the explosion of the explosive matter (although both this detonation and this explosion are discharges).
As mentioned before, the invention requires the use of energetic materials, either explosives or propellants, to generate a detectable seismic signal at some distances. A short representative list of explosives used in oil and gas exploration and production operations is shown in Table 1. The enthalpy of reaction is used to approximate the energy released during the explosion as detailed in the following references incorporated herein by reference:
Representative Explosives
(kJ g−1)
(g cm−3)
(m s−1)
Lead Azide
For the present invention, suitable "noisy particles" should be small enough to be pumped during a fracturing treatment but sufficiently energetic to generate a signal that can be detected by geophones or accelerometers mounted in the well being fractured, in one or more observation wells, or on the surface. It is further preferred that the dimensions of the explosive device or material be on the same scale as the proppant so that they will not be segregated as the fracturing fluid/slurry travels down the fracture. From field experience pumping proppant, fibers, and proppant flowback control materials, the representative sizes of particles that can be pumped with 20/40 proppant are listed in Table 2.
Minimum and maximum power estimates for the seismic emissions of
"pumpable" explosive particulate material
Estimate of
Estimate of
Min. Acoustic
Max. Acoustic
ΔHpart, RD>
ΔHpart, LA
Source Power
Source Power
1.1 � 10−4
1.0 � 10−3
3.8 � 10−6
Particles of these dimensions are typically smaller than most detonating devices in use today, and the physical dimensions of energetic materials do have a significant effect on the initiation and propagation of energetic fronts in the device. However, miniaturization of explosive sources is an area of active research for a number of civilian and military applications as discussed in D. Scott Steward, Towards the Miniaturization of Explosive Technology, Proceedings of the 23rd International Conference on Shock Waves, 2001, herein incorporated by reference. The minimum dimension for lead azide, a common primary explosive is on the order of 60 μm, therefore quite compatible with the construction of explosive devices of dimensions sufficiently small to be pumped into a fracture.
Although the enthalpy of even small explosive pellets, ΔHpart, is quite high as shown in Table 2, only a fraction of the total energy is emitted as seismic (acoustic) radiation, fs, over a detectable frequency range. For the following calculations, we will assume that detectable frequency range to be between 30 and 130 Hz (although frequencies as low as 1 Hz and as high as 10 Khz may be detectable).
The value of fs is difficult to determine, and is dependant on the size of the charge and the environment of the explosion. At the low end, the fraction of energy emitted as seismic radiation has been estimated as fs˜0.001. A high estimate can be made based on the results for underwater detonations reported on in D. E. Weston, Underwater Explosions as Acoustic Sources, Proc. Phys. Soc., Vol. 76, No. 2, pp 233–249. This paper reports the measured absolute acoustic source levels of 0.002, 1, and 50 lbm charges of TNT placed at various depths in seawater. The enthalpy change for the explosive detonation of 0.002 lbm (0.9 g) of TNT is ˜4.3 kJ. From
Ubndwth=4πr2ΦA (1)
the acoustic energy emitted by the 1 g TNT charge over the 30–130 Hz bandwidth was ˜0.13 kJ. Therefore fs˜0.13 kJ/4.3 kJ=0.03. If we assume that the energy is released in only a few cycles, a reasonable estimate considering the high detonation velocities for these materials, then the power of the acoustic pulse generated by a noisy particle is:
I0˜νfsΔHpart (2)
where, ν=seismic wave frequency (80 Hz is assumed for the calculations).
Based on these estimates for fs, a single "pumpable" explosive particle can generate 0.1–22 W of power within the 30–130 Hz frequency range.
If an implosive particle is used as an acoustic source, for example a glass microsphere, then the energy contained in the particle is,
U=PhydVsphere (3)
Assuming particle radius Rsphere˜0.8 mm and a hydrodynamic pressure of 10,000 psi, the total energy of the particle is ˜1.8�10−2 J. Again assuming fs˜0.001–0.03, and that the event is completed in one cycle, it can be estimated that the emitted power is between about 0.001 and 0.04 W.
Standard downhole geophones can typically detect particle velocity amplitudes in the magnitude of Alimit˜4�10−8 ms−1.
To a first approximation, accounting for both spherical wavefront spreading and signal attenuation due to internal friction, the amplitude of seismic waves generated by a point source an explosion can be assumed to decay according to,
By rearranging equation (4) the magnitude of a detectable event as a function of r can be shown to be:
In order for the source to be detectable it must generate a signal with an average power of:
W0=2πA0 2r0 2ρc (6)
Substituting (5) into (6) yields:
Experimental data for Q comes from a series of studies reported on in S. T. Chen, E. A. Eriksen, and M. A. Miller, Experimental studies on downhole seismic sources, Geophysics, Vol. 55, No. 12, pp 1645–1651, December, 1990; S. T. Chen, L. J. Zimmerman, and J. K. Tugnait, Subsurface imaging using reversed vertical seismic profiling and crosshole tomographic methods, Geophysics, Vol. 55, No. 11, pp 1478–1487, November, 1990, and S. T. Chen and E. A. Eriksen, Experimental studies on downhole seismic sources, Geophysics, Presented at the 59th Ann. Internat., Mtg., Soc. Expl., Geophys., Expanded Abs, pp 812–815, 1989.
These particular studies are appropriate for the present invention in that they used relatively small, 10–23 g, charges of dynamite as sources for reverse vertical seismic profiling. Signals were detected at distances of 122 to 366 m. Using equation (6) and values for Q, c, and λ obtained from a study reported on in S. T. Chen, E. A. Eriksen, and M. A. Miller, Experimental studies on downhole seismic sources, Geophysics, Vol. 55, No. 12, pp 1645–1651, December, 1990, the required power of the signal source, for two difference sandstones, can be estimated. Based on the results, a graph of required power as a function of the separation of source from detector is shown in
In one embodiment of the present invention, relatively large explosive charges are obtained by agglomerating or building a network out of smaller particles—thereby increasing the signal strength and overcoming the energy limit imposed by the particle size. For example, large explosive charges can be created in situ by pumping explosive material fabricated in a fibrous form that builds a continuous network within the fracture. Although the mass of the individual fibers is small, the mass of the connected fibrous network is quite large. A comparison with the fiber assisted transport (FAT) process provides an estimate of the size of the explosive charges that can be constructed in situ by this method. Polymeric fibers have been pumped in fracturing fluids at concentrations in excess of 10 g L−1 with proppant concentrations up to 1.5 kg added per liter of fluid. Accounting for the higher density, it is possible to pump at least 12 g L−1 of RDX or TNT. At these concentrations there exists a continuous network of fibers sufficiently entangled that it can support and transport proppant. (see Vasudevan, S., Willberg, D. M., Wise, J. A., Gorham, T. L., Dacar, R. C., Sullivan, P. F., Boney, C. L., Mueller, F., "Field Test of a Novel Low Viscosity Fracturing Fluid in the Lost Hills Field, Calif." paper SPE 68854 presented at the 2001 SPE Western Regional Conference, Bakersfield, Calif., U.S.A., March 28–30). If 5–10 kg of proppant is placed per square meter of fracture, typical for a fracture in hard rock formations, then the concentration of explosive material per area in the fracture is 63–126 g m−2. A 1 m disk in the fracture contains between about 50 and 100 g of explosive, much larger charges then those used in the S. T. Chen et al. references above.
According to one embodiment of the present invention, the explosive and detonators are constructed in a spherical shape as shown in
According to another embodiment of the present invention, exposure to either the treating fluid or the fracturing fluid itself triggers the detonation/ignition (discharge) of the reactive particle. For example a water reactive primer, such as an alkali metal, triggers detonation. In this embodiment a shell either 1) with a controlled permeability to water, or 2) that slowly degrades or dissolves, covers the particle. When water penetrates this shell it activates the primer, which in turn ignites or detonates the particle. The composition and construction of the shell is such that detonation/ignition is sufficiently delayed in time so that it will occur when the particle is well down the fracture. An example of a protective shell is slowly hydrolyzing polyester. The advantage of this embodiment is that the signal is generated real-time during the treatment. An engineer monitoring the treatment observes the growth of the fracture, and fluid placement, while the job is still in progress. Information from these observations is used to update or modify the treatment in a timely manner. Using a mix of different shell thicknesses on different particles further provides the ability to "time stamp" the signals: the particles of different shell thicknesses detonate/ignite at different, specified, time intervals, providing a "movie" of the evolution of the fracture geometry.
A variation of this embodiment is to allow the noisy particle to signal the production of oil or condensate. In this situation the shell is made of a material that reacts, softens, weakens or becomes more permeable to water upon exposure to oil produced by the reservoir. Again the water-reactive primer detonates or ignites the particle upon exposure to the connate or produced water that is commingled with the produced oil/condensate. The particular advantage of this variation is that it gives the practitioner insight into the geometry of the effective producing geometry of the fracture in some reservoirs.
In yet another embodiment of this invention, implosive particles, such as hollow glass spheres, are added to the slurry. The acoustic signal is released when the sphere is crushed, subjected to anisotropic stress, or ruptured by the hydrostatic pressure after mechanical or chemical degradation of the shell (the skin of the hollow sphere). The advantage of this embodiment is that these particles are relatively safe to deploy as compared with explosive/energetic particles, and their trigger mechanism is relatively simple. However, the major disadvantage of this embodiment is the low energy content of the particles, therefore it is best used in combination with detectors mounted close to the hydraulic fracture, for example in the well from which the fracture is being generated. One method is to place the detectors in the wellbore below the fracture, preferably with a shield to protect them from proppant.
In yet another embodiment of the present invention, different types of particle materials or particle materials embedded into different type of protective shells are used to allow the detonation/ignition/combustion (discharge) to occur, one-by-one over time in a random fashion or triggered by different events such as the fracture closure, the entry of specific type of formation fluids etc.
As mentioned before, it may be advantageous to use small pumpable explosive/combustible particles included in the fracturing fluid that by agglomerating, or by creating extended networks within the fracture, form relatively large charges in situ. This embodiment greatly increases the size of the seismic signal generated in the hydraulic fracture. Depending on the Q of the formation, or the location of the detectors with respect to the hydraulic fracture, the acoustic signature generated by an explosive particle approximately 1 mm in diameter may be undetectable but the agglomerate allows a detectable acoustic signature. In one embodiment the detonators (primers) and the explosive are pumped separately. detonation
In yet another preferred embodiment, the explosive is fabricated as a fiber, ribbon or long rod. Alternatively the explosives are pumped as a granular material. In both situations the method relies on the discharge of multiple grains, ribbons, or fibers to generate the acoustic signature. One advantage of a fiber (or rod-shaped) material is the high degree of connectivity in fibrous suspensions—this helps guarantee that a detonation wave propagates thoroughly throughout all the explosives in the fracture. A representative example is shown in
In a variation of this embodiment, the proppant itself is coated with an explosive or ignitable material, similar to resin coated proppant (RCP) and the detonators/primers are pumped separately. This variation of the invention also ensures that the source of the acoustic events is co-located with the proppant.
Combinations of different types of "noisy materials" may be particularly useful. For example water-activated particles may be pumped simultaneously with crush-activated particles. The water-activated particles give an engineer monitoring the operation real-time information regarding the growth of the fracture during the treatment. The crush activated particles give the engineer information regarding the geometry of the fracture at closure. The "noise" may also signal the exact instant of fracture closure and therefore allows an unambiguous determination of the closure pressure. The important of the closure pressure is emphasized in S. N. Gulragani and K. G. Nolte, Appendix to Chapter 9: Background for Hydraulic Fracturing Pressure Analysis Techniques, p A9-1 to A9-16 in Reservoir Stimulation, 3rd Edition, M. J. Economides and K. G. Nolte, editors New York, John Wiley and Sons Ltd, 2000. Closure pressure is typically obtained by observing changes, unfortunately sometimes extremely small, in the slope of the graph of pressure as a function of time during a short pre-treatment (often called a Datafrac) performed without proppant. Note that this application does not requiring the full complement of detectors and data processing procedures required for actual fracture imaging. In this embodiment crush activated noisy particulate is included in the Datafrac and/or in the actual treatment. The noisy particles generate the acoustic/seismic signal when the fracture walls close on the particulates. The closure of the fracture to a width smaller than the diameter of the explosive particles is positively identified. If the pressure is being monitored in this process then the closure pressure, or range of closure pressure, is determined. Furthermore, this process may be replicated at the end of the actual fracturing treatment. By comparing the results, variations in closure pressure caused by fluid imbibition into the formation, or other factors, may be monitored.
The noisy particles of the invention may be introduced into the treatment fluid at the wellhead through a ball injector or similar device as shown in
As shown in
The noisy particles have another use. The detonation, ignition or exothermic reaction may be used to create localized high rate fluid motion. This motion may be used to mix chemicals in the fluid in the proppant pack, to initiate reactions in the fluid in the proppant pack, to break capsules containing chemicals (for example, acids) in the proppant pack, and to create localized high shear in the fluids in the proppant pack.
|Cited Patent
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|Hradel Joseph R
|Detonation of unprimed base charges
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|Levenson Sol J
|Shock absorber tester
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|Dow Chemical Co
|High pressure explosive compositions and method using hollow glass spheres
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|Oct 13, 1970
|Exxon Production Research Co
|Method of exploding using reflective fractures
|Mar 26, 1968
|Feb 9, 1971
|Talley Frac Corp
|Well fracturing method using explosive slurry
|Feb 3, 1969
|Jul 20, 1971
|Cities Service Oil Co
|Stimulation of recovery from underground deposits
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|Jan 30, 1973
|Amoco Prod Co
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|Jul 23, 1974
|Talley Frac Corp
|Liquid explosive for well fracturing
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|The United States Of America As Represented By The United States Energy Research And Development Administration
|Method for describing fractures in subterranean earth formations
|Mar 28, 1983
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|Orszagos Koolaj Es Gazipari Troszt
|Charge liner for hollow explosive charges
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|Background for Hydraulic Fracturing Pressure Analysis Techniques-S.N. Gulragani and K.G. Nolte, Appendix to Chapter 9: Reservoir Stimulation, 3<SUP>rd </SUP>Edition, M.J. Economides and K.G. Nolte-p A9-1 to A9-16.
|Creating an Explosion: The theory and practice of detonation and solid chemical explosives-J.A. Burgess and G. Hooper, Physics in Technology, Nov. 1977, pp. 257-265.
|DBX(TM) Seismic Energy Source Technical Information Reference MSDS # 1316-Dyno Nobel Inc.
|Experimental Studies of Downhole Seismic Sources-S.T. Chen and E.A. Eriksen ,Geophysics, presented at the 59<SUP>th </SUP>Ann, Internet, Mtg., Soc. Expl., Geophys., Expanded Abs.
|Experimental Studies on Downhole Seismic Sources-S.T. Chen, E.A. Eriksen and M. A. Miller, Geophysics, vol. 55, No. 12, pp. 1645-1651, Dec. 1990.
|SPE 15214-Monitoring Hydraulic Fracture Stimulations with Long-Period Seismometers to Extract Induced Fracture Geometry-F.J. Mauk and K.D. Mahrer.
|SPE 21834-Microseismic Logging: A New Hydraulic Fracture Diagnostic Method.-K.D. Mahrer.
|SPE 27506-Data Gathering for a Comprehensive Hydraulic Fracturing Diagnostic Project: A case Study.-L.S. Truby, R.G. Keck and R.J. Withers.
|SPE 30507-Microseismic Mapping of Hydraulic Fractures Using Multi-Level Wireline Receivers.-N.R. Warpinski, B.P. Engler, C.J. Young, R. Peterson, P.T. Branagan and J.E. Fix.
|SPE 30738-Hot Dry Rock: A Versatile Alternative Energy Technology-D.V. Duchane.
|SPE 36450-Microseismic Monitoring of the B-Sand Hydraulic Fracture Experiment at the DOF/GRI Multi-Site Project.-N.R. Warpinski, T.B. Wright, J.E. Uhl, P.M. Drozda, R.E. Peterson and P.T. Branagan.
|SPE 38573-Microseismic and Deformation Imaging of Hydraulic Fracture Growth and Geometry in the C Sand Interval, GRI/DOE M-Site Project.-N.R. Warpinski, P.T. Branagan, R.E. Peterson, J.E. Fix, J.E. Uhl, B.P. Engler and R. Wilmer.
|SPE 38574-Progagation of a Hydraulic Fracture into a Remote Observation Wellbore: Results of C-Sand Experimentation at the GRI/DOE M-Site Project.-P.T. Branagan, R.E. Peterson, N.R. Warpinski, S.L. Wolhart and R.E.Hill.
|SPE 38576-A Systematic Study of Fracture Modeling and Mechanics Based on Data from GRI/DOE M-Site Project-T.B. Wright and T.W. Green.
|SPE 38577-Cotton Valley Hydraulic Fracture Imaging Project.-Ray N. Walker, Jr.
|SPE 40014-Mapping Hydraulic Fracture Growth and Geometry Using Microseismic Events Detected by a Wireline Retrievable Accelerometer Array.-N.R. Warpinski, P.T. Branagan, R.E. Peterson, S.L. Wolhart and J.E. Uhl.
|SPE 47315-Monitoring and Management of Fractured Reservoirs Using Induced Microearthquake Activity.-A. Jupe, R. Jones, B.Dyer and S. Wilson.
|SPE 57593-Microseismic Monitoring of the B-Sand Hydraulic-Fracture Experiment at the DOE/GRI Multisite Project.-N.R. Warpinski, T.B. Wright, J.E. Uhl, B.P. Engler, P.M. Drozda, R.E. Peterson and P.T. Branagan.
|SPE 63034-East Texas Hydraulic Fracture Imaging Project: Measuring Hydraulic Fracture Growth of Conventional Sandfracs and Waterfracs.-Michael J. Mayerhofer, Ray N. Walker Jr., Ted Urbancic and James T. Rutledge.
|SPE 64434-State-of -the-Art in Hydraulic Fracture Diagnostics. C.L. Cippola and C.A. Wright.
|SPE 68854-Field Test of a Novel Low Viscosity Fracturing Fluid in the Lost Hills Field, California-S. Vasudevan, D.M. Willberg, J.A. Wise, T.L. Gorham, R.C. Dacar, P.F. Sullivan, C.L. Boney and F. Mueller.
|SPE 71649-Analysis and Prediction of Microseismicity Induced by Hydraulic Fracturing. N.R. Warpinski, S.L. Wolhart and C.A. Wright.
|SPE 77440-Microseismic Imaging of Hydraulic Fracture Complexity in the Barnett Shale. S.C. Maxwell, T.I. Urbancic, N. Steinsberger and R. Zinno.
|SPE 77441-Integrating Fracture Mapping Technologies to Optimize Stimulations in the Barnett Shale.-M.K. Fisher, C.A. Wright, B.M. Davidson, A.K. Goodwin, E.O. Fielder, W.S. Buckler and N.P. Steinsberger.
|SPE 77442-A Practical Guide to Hydraulic Fracture Diagnostic Technologies.-R. D. Barree, M.K. Fisher and R. A. Woodroof.
|SPE18538-Uplifts and Tilts at Earth's Surface Induced by Pressure Transients from Hydraulic Fractures. -Ian D. Palmer.
|SPE49194-Carthage Cotton Valley Fracture Imaging Project-Imaging Methodology and Implications.-R.N. Walker Jr., R.J. Zinno, J.B. Gibson, Ted Urbancic and Jim Rutledge.
|Subsurface Imaging Using Reversed Vertical Seismic Profiling and Crosshole Tomographic Methods.-S.T. Chen, L.J. Zimmerman and J.K. Tugnait, Geophysics, vol. 55, No. 11, pp. 1478-1487, Nov. 1990.
|Towards the Miniaturization of Explosive Technology-Proceedings of the 23<SUP>rd </SUP>International Conference on Shock Waves, 2001-D. Scott Stewart.
|Underwater Explosions as Acoustic Sources-D.E. Weston, Proc. Phys. Soc., vol. 76, No. 2, pp. 233-249.
|VIBROGEL(TM) Seismic Energy Source Technical Information Reference MSDS (TM) 1019-Dyno Nobel Inc.
|Citing Patent
|Filing date
|Publication date
|Dec 4, 2006
|Dec 2, 2008
|The Board Of Trustees Of The Leland Stanford Junior University
|Apparatus and method for hydraulic fracture imaging by joint inversion of deformation and seismicity
|Nov 9, 2010
|Schlumberger Technology Corporation
|Identifying the Q-factor using microseismic event generated S-coda waves
|Mar 26, 2007
|Jan 25, 2011
|Schlumberger Technology Corporation
|Determination of downhole pressure while pumping
|Mar 15, 2011
|Schlumberger Technology Corporation
|System, method, and apparatus for fracture design optimization
|Oct 22, 2008
|Jun 28, 2011
|Westerngeco L.L.C.
|Active seismic monitoring of fracturing operations
|May 19, 2009
|May 1, 2012
|Oxane Materials, Inc.
|Method of manufacture and the use of a functional proppant for determination of subterranean fracture geometries
|May 20, 2011
|Jul 3, 2012
|Westerngeco L.L.C.
|Active seismic monitoring of fracturing operations
|Apr 9, 2009
|Aug 28, 2012
|Baker Hughes Incorporated
|Electrolocation apparatus and methods for mapping from a subterranean well
|Feb 11, 2011
|Aug 13, 2013
|Dan Angelescu
|Passive micro-vessel and sensor
|Mar 15, 2012
|Oct 29, 2013
|Schlumberger Technology Corporation
|System and method for managing a subterranean formation
|May 19, 2009
|Apr 8, 2014
|Halliburton Energy Services, Inc.
|Formation treatment using electromagnetic radiation
|Feb 3, 2009
|May 20, 2014
|Method of estimating well disposal capacity
|Aug 1, 2012
|Aug 5, 2014
|Baker Hughes Incorporated
|Apparatus and methods for providing information about one or more subterranean feature
|Aug 1, 2012
|Sep 23, 2014
|Baker Hughes Incorporated
|Electrolocation apparatus and methods for providing information about one or more subterranean feature
|May 20, 2011
|Jan 20, 2015
|Westerngeco L.L.C.
|Active seismic monitoring of fracturing operations and determining characteristics of a subterranean body using pressure data and seismic data
|Apr 10, 2012
|Jan 27, 2015
|Halliburton Energy Services, Inc.
|Method and apparatus for generating seismic pulses to map subterranean fractures
|Jul 13, 2012
|Jul 21, 2015
|Schlumberger Technology Corporation
|Heterogeneous proppant placement in a fracture with removable extrametrical material fill
|Aug 18, 2008
|Jul 21, 2015
|Westerngeco L.L.C.
|Determining characteristics of a subterranean body using pressure data and seismic data
|Mar 20, 2013
|Aug 4, 2015
|Baker Hughes Incorporated
|Method of determination of fracture extent
|Mar 26, 2007
|Aug 11, 2015
|Schlumberger Technology Corporation
|Wireless logging of fluid filled boreholes
|Jul 2, 2012
|Sep 8, 2015
|Westerngeco L.L.C.
|Active seismic monitoring of fracturing operations
|Dec 7, 2012
|Feb 9, 2016
|Schlumberger Technology Corporation
|Encapsulated explosive pellet
|May 31, 2012
|May 10, 2016
|Schlumberger Technology Corporation
|Explosive pellet
|Dec 4, 2006
|Jun 7, 2007
|Paul Segall
|Apparatus and method for hydraulic fracture imaging by joint inversion of deformation and seismicity
|Dec 28, 2006
|Sep 20, 2007
|Theodore Lafferty
|Method And Apparatus For Hydraulic Fracturing And Monitoring
|Feb 6, 2008
|Sep 4, 2008
|William John Bailey
|System, method, and apparatus for fracture design optimization
|Mar 26, 2007
|Oct 2, 2008
|Schlumberger Technology Corporation
|Determination of downhole pressure while pumping
|Mar 26, 2007
|Oct 2, 2008
|Schlumberger Technology Corporation
|Wireless Logging of Fluid Filled Boreholes
|Dec 27, 2007
|Jul 2, 2009
|Yoscel Suarez
|Identifying the q-factor using microseismic event generated s-coda waves
|Apr 9, 2009
|Oct 15, 2009
|Bj Services Company
|Electrolocation apparatus and methods for mapping from a subterranean well
|Nov 26, 2009
|Oxane Materials, Inc.
|Method Of Manufacture And The Use Of A Functional Proppant For Determination Of Subterranean Fracture Geometries
|Aug 18, 2008
|Feb 18, 2010
|Beasley Craig J
|Determining characteristics of a subterranean body using pressure data and seismic data
|Oct 22, 2008
|Apr 22, 2010
|Beasley Craig J
|Active seismic monitoring of fracturing operations
|Feb 3, 2009
|Dec 30, 2010
|Method of estimating well disposal capacity
|May 19, 2009
|May 12, 2011
|Halliburton Energy Services, Inc.
|Formation Treatment Using Electromagnetic Radiation
|Sep 8, 2011
|Westerngeco L.L.C.
|Active Seismic Monitoring of Fracturing Operations
|Feb 18, 2011
|Mar 1, 2012
|Baker Hughes Incorporated
|Apparatus and methods for providing information about one or more subterranean variables
|Sep 14, 2012
|Nov 7, 2013
|Los Alamos National Security, Llc
|Composition and method for locating productive rock fractures for fluid flow
|Jul 17, 2013
|Jan 22, 2015
|Lawrence Livermore National Security, Llc
|Encapsulated microenergetic material
|Mar 13, 2007
|Sep 20, 2007
|Schlumberger Canada Limited
|Method and apparatus for hydraulic fracturing and monitoring
|Mar 26, 2008
|Oct 2, 2008
|Services Petroliers Schlumberger
|Determination of downhole pressure while pumping
|Jul 31, 2012
|Apr 25, 2013
|Schlumberger Canada Limited
|Explosive pellet
|Jul 31, 2012
|Aug 8, 2013
|Schlumberger Canada Limited
|Explosive pellet
|Apr 10, 2012
|Oct 17, 2013
|Halliburton Energy Services, Inc
|Method and apparatus for generating seismic to map subterranean fractures
|Nov 14, 2013
|Jun 12, 2014
|Schlumberger Canada Limited
|Encapsulated explosive pellet
|Jun 12, 2014
|Jan 22, 2015
|Lawrence Livermore National Security, Llc
|Encapsulated microenergetic material
|U.S. Classification
|166/250.1, 166/271, 166/308.1, 166/299, 166/280.2
|International Classification
|Cooperative Classification
|European Classification
|Jul 13, 2004
Owner name: SCHLUMBERGER TECHNOLOGY CORPORATION, TEXAS
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:WILLBERG, DEAN;DESROCHES, JEAN;BABOUR, KAMAL;AND OTHERS;REEL/FRAME:014842/0211;SIGNING DATES FROM 20040423 TO 20040518
|May 3, 2010
|Fee payment
Year of fee payment: 4
|Apr 16, 2014
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The Beauty of Flowers
Pink Flowers, Favorite Flowers, Beautiful Flowers, Peony Farm, Pink Peonies
My favorite flower - the peony. I have actually never seen one in real life because I live in Florida and they don't grow here.
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climbing roses | Tumblr
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This is GORGEOUS! #DailyDoseofColor Luxembourg Gardens in Paris, France
Luxembourg Gardens in Paris, France (by Rebecca Plotnick)
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This is GORGEOUS! Luxembourg Gardens in Paris, France
Spring flower garden
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Blue Mason Jars, Pink Flowers, Wedding Ideas, Wedding Flowers, Pretty Flower
pink astilbe #centerpiece Photography: Carly McCray Photography Read More: #Romantic Life Style| http://romantic-life-style-321.blogspot.com
Pink astilbes are one of @Lauren Dailey-Conrad's favorite flowers, and she loves displaying them in a vintage blue Ball jar!
Pink astilbe in blue mason jar / add soft burlap tie at mouth of jar and do fuller bunches of astilbe (add some white, as well)
Pink astilbe flowers with blue mason jars. Can you say PERFECT for a spring wedding!?
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Blue Ball jars with pink flowers, I loves you.


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Memorial Week Sale
May 21st- May 31st
A percentage of all sales will be donated to Animal Shelters.
It's here, the Healthiest Dog Food exclusively from The Cat Made Them, Mendel's Homemade Chicken Dog Food. Our clients asked for it and we have finally come up with the perfect recipe. Our testing clients have told us that their dogs have stopped itching, they have more energy and they can't wait to eat. Our food only uses American ingredients and the chicken is 100% USDA chicken breasts.You can feed your dog less of our food because of the density, we don't add fillers and extra water to fill our jar. Yes, all our food is sent in glass jars, no tinny taste and you see exactly what you are getting. Our food is 100% human grade. All the nutrition they need comes from all natural sources. Our food has no added sodium, no preservatives and no additives.
See more information on our product's page.
We hope all our dogfriends enjoythe special treats and food we have made for them.
If you think we can make something that is not on our product page, please email us:email@example.com
We offer a 100% Guarantee, if you are not satisfied, send back the package for a full Refund.
What makes our treats and food different? Everything in our treats is from the USA. We only use USDA chicken breast and lean USDA beef. Our fish comes from the waters of Alaska and is never farm-raised. All our treats are hand cut, dehydrated and air-cooled by our exclusive system to lock in the freshness.
Chicken Jerky
Beef Jerky


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Video: SC deputy shoots knife-wielding man
Suspect approached a deputy as he conducted a traffic stop and pulled a knife on him
By PoliceOne Staff
CLARENDON COUNTY, S.C. — Dash-cam video captured the shooting of a man who from underneath an umbrella, approached a deputy conducting a traffic stop and pulled a knife on him.
Clarendon County Deputy Danny Graham had just issued a speeding ticket to a motorist on August 13 when a man walked down the road toward the scene of the traffic stop, Sheriff Randy Garrett told WLTX.
Police say Anthony Pearson, 37, pulled out a seven-inch butcher knife and lunged at the deputy.
In the video, Graham backs up, draws his weapon and points it at Pearson, who was wounded.
"It's a justified shoot in my book," Garrett said. "He's clear."
It is unclear why Pearson attacked, but he was once shot in the shoulder in an encounter with law enforcement in New York, according to the station. He was treated at the hospital and last reported to be awaiting a bond hearing on charges of attempted murder of a police officer.
Garrett offered to give Graham the day off after the shooting, but he declined. The motorist still received the ticket.
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