WO2005124395A2 - Methods and apparatus for measuring streaming potentials and determining earth formation characteristics - Google Patents
Methods and apparatus for measuring streaming potentials and determining earth formation characteristics Download PDFInfo
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- WO2005124395A2 WO2005124395A2 PCT/IB2005/002468 IB2005002468W WO2005124395A2 WO 2005124395 A2 WO2005124395 A2 WO 2005124395A2 IB 2005002468 W IB2005002468 W IB 2005002468W WO 2005124395 A2 WO2005124395 A2 WO 2005124395A2
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V3/00—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation
- G01V3/18—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging
- G01V3/26—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device
- G01V3/265—Operating with fields produced by spontaneous potentials, e.g. electrochemicals or produced by telluric currents
Definitions
- This invention relates broadly to the hydrocarbon industry. More particularly, this invention relates to apparatus and methods for measuring streaming potentials resulting from pressure transients in an earth formation traversed by a borehole. This invention also relates to manners of making determinations regarding earth formation characteristics as a result of streaming potential measurements.
- One such characteristic is the permeability of the formation at different depths thereof, although the invention is not limited thereto.
- the fluid movement produces detectable electrokinetic potentials of the same frequency as the applied sonic energy and having magnitudes at any given location directly proportional to the velocity of the fluid motion at that location and inversely proportional to the square of the distance from the locus of the streaming potential pulse. Since the ' fluid velocity was found to fall off from its initial value with increasing length of travel through the formation at a rate dependent in part upon the permeability of the formation rock, it was suggested that the magnitude of the electrokinetic potential at any given distance from the pulse provided a relative indication of formation permeability. By providing a ratio of the electrokinetic potential magnitudes (sinusoidal amplitudes) at spaced locations from the sonic generator, from which electrokinetic skin depth may be derived, actual permeability can in turn be determined.
- the borehole tool includes a pad device which is forced into engagement with the surface of the formation at a desired location, and which includes means for injecting fluid into the formation and electrodes for measuring electrokinetic streaming potential transients and response times resulting from the injection of the fluid.
- the fluid injection is effectively a pressure pulse excitation of the formation which causes a transient flow to occur in the formation.
- Chandler suggests a measurement of the characteristic response time of the transient streaming potentials generated in the formation by such flow in order to derive accurate information relating to formation permeability.
- U.S. Patent #5,503,001 (1996), Wong proposed a process and apparatus for measuring at finite frequency the streaming potential and electro-osmotic induced voltage due to applied finite frequency pressure oscillations and alternating current.
- the suggested apparatus includes an electromechanical transducer which generates differential pressure oscillations between two points at a finite frequency and a plurality of electrodes which detect the pressure differential and streaming potential signal between the same two points near the source of the pressure application and at the same frequency using a lock- in amplifier or a digital frequency response analyzer.
- the apparatus of the invention measures the differential pressure in the porous media between two points at finite frequencies close to the source of applied pressure (or current) , it greatly reduces the effect of background caused by the hydrostatic pressure due to the depth of the formation being measured.
- Wong states that attempts to measure the streaming potential signal with electrodes at distances greater than one wavelength from each other are flawed since pressure oscillation propagates as a sound wave and the pressure difference would depend on both the magnitude and the phase of the wave, and the streaming potential signal would be very much lower since considerable energy is lost to viscous dissipation over such a distance.
- Wong states that application of a DC flow to a formation and measurement of the response voltage in the time domain will not work in low permeability formations since the longer response time and very low streaming potential signal is dominated by drifts of the electrodes' interfacial voltage over time.
- the Chandler device will work only in drilled boreholes prior to casing and requires that the tool be stationed for a period of time at each location where measurements are to be made.
- the Chandler device cannot be used as an MWD/LWD (measurement or logging while drilling) device, is not applicable to finished wells for making measurements during production, and cannot even be used on a moving string of logging devices.
- Another object of the invention is to provide methods of characterizing fractures in a formation using streaming potential measurements.
- a further object of the invention is to provide methods of determining one or more of formation permeability, skin permeability, effective fracture permeability, and horizontal and vertical permeabilities of a formation using streaming potential measurements.
- a first embodiment of the invention relates to measuring streaming potential while drilling a borehole.
- measurement-while-drilling (MWD) and logging-while-drilling (LWD) applications will be considered interchangeable.
- a second embodiment of the invention relates to measuring streaming potential with a borehole tool which is adapted to make measurements while moving through the borehole.
- a third embodiment of the invention relates to measuring streaming potential with apparatus which is permanently installed (e.g., cemented) about the wellbore. All embodiments of the invention can be utilized to find characteristics of the formation.
- the streaming potential measurements can be used to track flow of fluids in the formation.
- this information may be used to find the permeability of the formation in different strata about the borehole and/or to find and characterize fractures in the formation.
- Fig. 1 is a schematic diagram of a completed horizontal well having electrodes deployed thereabout for purposes of measuring streaming potentials.
- Fig. 2 is a schematic diagram of electrodes mounted on insulated joint sections of the sand-screen completion of Fig. 1.
- Fig. 3 is a plot of pressure transients measured for two of the zones shown in Fig. 1.
- Fig. 4 is a plot showing pressure transients and streaming potentials over time for the well of Fig. 1.
- Fig. 5 is a plot showing the streaming potentials measured by electrodes in zone 2 of Fig. 1.
- Fig. 6 is a plot showing the streaming potentials measured by electrodes in zone 3 of Fig. 1.
- Fig. 7 is a plot showing voltage drifts of the electrodes in zone 1 of Fig. 1.
- Fig. 8 is a plot showing streaming potentials measured by electrodes in zone 1 of Fig. 1.
- Fig. 9 is a schematic diagram of the well of Fig. 1 showing qualitative determinations made from information obtained by the electrodes disposed about the well.
- Fig. 9a is a schematic representing a forward model of a heterogeneous formation.
- Fig. 9b is a plot of streaming potentials generated by the forward model of Fig. 9a.
- Fig. 9c is a schematic representing a forward model of a fractured formation.
- Fig. 9d is a plot of streaming potentials generated by the forward model of Fig. 9c.
- Fig. 10 is a schematic diagram of a completed vertical well having electrodes deployed thereabout for purposes of measuring streaming potentials.
- Fig. 11 is a schematic diagram of the manner in which electrodes were mounted in the completed well of Fig. 10.
- Fig. 12 is a plot of the uphole pressure applied to the well of Fig. 10 over a period of days.
- Fig. 13 is a plot showing the uphole pressure of Fig. 12 and the streaming potentials measured by a series of electrodes in a reservoir location shown in Fig. 10.
- Fig. 14 is an enlarged version of a portion of Fig. 13.
- Fig. 15 is a plot showing the uphole pressure of Fig. 12 and the streaming potentials measured by a group of electrodes above the reservoir location.
- Fig. 16 is an enlarged version of a portion of Fig. 15.
- Fig. 17 is a plot showing the uphole pressure of Fig. 12 and the streaming potentials measured by a group of electrodes below the reservoir location.
- Fig. 18 is a schematic diagram of the well of Fig. 10 showing qualitative determinations made from information obtained by the electrodes disposed about the well.
- Fig. 18a is a schematic representing a forward model of a vertical producing well having a fracture.
- Fig. 18b is a plot of streaming potentials generated by the forward model of Fig. 18a.
- Fig. 19 is an enlarged version of a portion of Fig. 17 which is used to show the stability of the electrodes.
- Fig. 20 is a schematic diagram of an open hole completion with electrodes located about an insulated zone surrounding a tubing.
- Fig. 21 is a schematic diagram of a cased-hole completion with electrodes incorporated into the casing.
- Fig. 22 is a schematic diagram of an LWD tool with streaming potential electrodes disposed thereon.
- Fig. 23 is a schematic diagram of a wireline tool having streaming potential electrodes disposed thereon.
- Fig. 23a is a schematic representing a forward model of a wireline tool which is adapted to slit borehole mudcake .
- Fig. 23b is a plot of streaming potentials generated by the forward model of Fig. 23a with respect to an uninvaded zone .
- Fig. 23c is a plot of streaming potentials generated by the forward model of Fig. 23a with respect to an invaded zone .
- Fig. 23d is a plot generated by the forward model of Fig. 23a of the sensitivity of the streaming potential with respect to depth of invasion.
- Fig. 23e is a plot which shows an inversion for permeability of synthetic data and a best fit for a five parameter model .
- Pressure transients are created in the formation by many different operations that occur over the lifetime of a well such as drilling, mud invasion, cementing, water and acid injection, fracturing, and oil and gas production.
- Pressure transient testing is an established technique to determine reservoir properties such as permeability, reservoir size, and communication between different zones and between different wells.
- streaming potential transients associated with the pressure transients can also be used to determine these properties.
- the modeling of the reservoir pressure p can be carried out with multiphase flow models.
- the early time pressure and streaming potential transients are sensitive mainly to reservoir properties near the borehole, and the late time transients are sensitive to reservoir properties both near the borehole and farther away from the borehole.
- the measured transients By interpreting the measured transients in a time ordered fashion, reservoir properties at different distances to the borehole can be determined.
- the interpretation of pressure transients in this time ordered fashion is an established art. For example, early time pressure transients are used to determine damage to permeabilities or "skin", and late time pressure transients are used to determine reservoir boundaries.
- the drop in the streaming potential AV is related to Ap by
- the steady state streaming potential can only give information on the average value of a reservoir property and as a result is dominated by intervals with high values of
- the critical question in practice is whether the measurements can be made with sufficient quality: accuracy, spatial resolution, and stability over long time. It is difficult to get pressure transient data with high spatial resolution as the borehole is essentially an isobaric region. A pressure sensor placed inside the borehole cannot give detailed information on the pressure transients inside the formation if the formation is heterogeneous. To do so, it would be necessary to segment the borehole into hydraulically isolated zones, a difficult and expensive task to perform. On the other hand, the borehole is not an equipotential surface for electric current flow.
- streaming potential transients may be measured by an array of electrodes placed inside the borehole and electrically isolated (i.e., insulated) one from the other and can provide equivalent information to that of hydraulically isolated zone pressure transient testing because the streaming potential is determined by the pressure gradient.
- the streaming potential can be measured with a higher spatial resolution than hydraulically isolated zone pressure transient testing.
- insulated electrodes are deployed in or about a borehole or a well in order to measure streaming potential transients.
- the electrodes may be deployed on insulated sections of a drill pipe in while- drilling (MWD or LWD) applications, or on the body of a tool which is moved through the borehole in wireline logging applications.
- the electrodes may be deployed on an insulating sonde placed in an open hole for an open-hole completion, or on (or as part of) centralizers in sand-screen completions, or in insulation surrounding a casing in a cemented completion.
- the metal casings can serve as electrodes. Regardless of how the electrodes are deployed, DC voltage differences indicative of streaming potentials are measured between a reference electrode and other electrodes of an array. Initial voltage difference values between the reference electrode and other electrodes typically due to surface chemistry differences of the electrodes are subtracted from all data subsequent to the creation of pressure transients.
- the streaming potential transients are generated in any of various manners .
- the pressure difference between the formation and the borehole creates mud invasion, pressure transients and streaming potential transients.
- streaming potential transients are generated by providing the wireline tool with one or more cutting edges mounted on one or more retractable arms which cut slits across the mudcake while logging. Because of a large overbalancing pressure difference between the formation and the borehole, when the mudcake is slit, fluid will flow through the slit and the resulting pressure transient can be measured.
- streaming potential transients are generated by injection of completion fluid, cement, gravel, acids, fracturing propellant, water injection testing, production testing, etc.
- any change in the rate of production will also create streaming potential transients.
- a streaming potential transient will be created and will be measurable with high precision using the deployed electrodes .
- data related to streaming potential transients obtained by the electrodes is interpreted to provide useful information. Those skilled in the art will appreciate that the interpretation of pressure transient data (as opposed to streaming potential transient data) to obtain reservoir properties such as permeability is a well-established art.
- the pressure transients change with time rapidly, while in formations with low permeability, the pressure transients change slowly.
- the streaming potential transients produced by the pressure transients depend on the formation permeability in the same way as the pressure transients.
- the Poisson equation (3) is linear in the coupling constants L , since the coupling of the streaming potential back into the governing equations for the pressure by electro-osmosis is completely negligible. Therefore, the inversion for the coupling constants is a straightforward linear inversion. Indeed, the minimization of equation (10) is carried out in two steps. The first step is to fix R and vary L , and find the sub-optimal minimum of the mismatch by solving a linear problem for L . The solution gives L as a function of R . The sub-optimal minimum is then a function of R only: E sl (R) ⁇ E S (R,L(R)) ⁇ ( ID
- the measured streaming potential transients associated with the fluid movement in the formation can be used inter alia to: track movement of cement slurries during cementing thereby detecting possible cementing problems; track slurries carrying gravel thereby monitoring gravel packing; track acid movement during injection of acid into the formation as acid injection will create streaming potential transients; monitor fracturing of formations in real time; evaluate fracture jobs quantitatively; track water movement resulting from water injection; improve the effectiveness of pressure transient testing; and monitor reservoir parameter changes over long periods of time, including water saturation, relative permeability and water cut.
- Fig. 1 The horizontal production well 100 of Fig. 1 was completed in formation 105 with sand screens 114 (see Fig. 2) and segmented into three zones with external casing packers Ilia, 111b, 111c.
- Zone 1 The zone closest to the heel of the horizontal well is labeled as Zone 1, the middle zone as Zone 2, and the zone closest to the toe as Zone 3.
- Zone 3 Each zone was provided with a valve unit 113a, 113b, 113c respectively, extending through the screen 114, with two pressure sensors 115-1 and 115-2 associated with each valve unit 113 (see Fig. 2) .
- Electrodes 118 were deployed as discussed below.
- FIG. 2 deployment of the electrodes 118 according to the invention is seen.
- the well 100 is completed with sand-screen sections 114 which are coupled together by insulated joint sections 116 to form the completion string.
- the joint sections 116 are electrically insulated.
- Mounted in the middle of each joint section is a centralizer 118. Because of the weight of the completion string 114,116, the centralizers 118 are always in good contact with the formation 105.
- the centralizers 118 are equipped as electrodes with preferably high impedance voltage measurement circuits and are coupled to surface electronics by cable wires (not shown) .
- Appropriate centralizer hardware is described in PCT Application WO 02/053871.
- the completion string being made of metal, forms a short circuit for electrical currents.
- the screen sections 114 used to complete well 100 were fifteen feet long, and the joint sections 116 were five feet long. Since the insulated joint sections 116 of the completion string covered only a small area near the electrodes 118, much of the electrical currents were able to leak through the exposed screen sections 114, resulting in the reduction of signal level. However, as shown hereinafter, there still existed significant levels of signal to be measured. It should be noted that for quantitative interpretation, it is sufficient to include the current leakage in the forward modeling.
- Fig. 1 seven electrodes were provided per zone for a total of twenty-one electrodes (labeled 118-1, 118-2..., 118-21. With a fifteen foot screen section and a five foot joint section, the distance between neighboring electrodes in the same zone was approximately twenty feet. The distance between the nearest two electrodes in different zones was just over one hundred feet.
- Zone 1 is hydraulically isolated from Zone 2 and Zone 3. This is seen in Fig. 3, since Zone 1 pressure 125a is significantly higher than Zone 2 and Zone 3 pressures 125b, 125c thereby indicating isolation. Therefore, for the voltages of the electrodes in Zone 1 (118-1 through 118-7) , the reference electrode was chosen to be in Zone 2 or Zone 3, and for the voltages of the electrodes in Zone 2 and Zone 3, the reference electrode was chosen to be in Zone 1.
- the three electrical valves 113a, 113b, 113c, and a rod pump (not shown) at the formation surface were utilized to control the fluid flow.
- the fluid in the annulus of each zone flowed into the tubing through the valve opening.
- the pressure gauge 115-1 on the tubing side of the opening measured the tubing pressure
- the pressure gauge 115-2 on the annulus side measured the pressure in the annulus region between the formation and the screen.
- the annulus pressure was equal to the formation pressure.
- the Zone 2 and Zone 3 annulus pressures 125b, 125c were approximately equal, indicating that the two zones are in hydraulic communication.
- the Zone 1 annulus pressure 125a was higher, indicating that Zone 1 is hydraulically isolated.
- the Zone 2 valve and the Zone 3 valve were opened for three hours and then shut.
- Zone 2 annulus pressure shown as curve 125a in Figure 3, dropped 150 psi (from approximately 840 psi to approximately 690 psi) to the level of the tubing pressure immediately after the valve opening, and then started to build up back to the formation pressure.
- the Zone 3 annulus pressure is shown as curve 125b in Figure 3.
- the Zone 3 pressure buildup curve rose faster than the Zone 2 pressure buildup curve, indicating that Zone 3 is more permeable than Zone 2.
- the pressure gradient existed mainly in the damaged zone near the well.
- the permeability of the damaged zone, or skin is known to be lower than that of the undamaged formation. If the coupling constant between the pressure gradient and the electric current is also lower in the skin than in the formation, then the streaming potential should increase with time initially when the pressure gradient diffuses from the skin to the undamaged formation. At later times, the pressure builds back to the formation pressure, the pressure gradient diminishes and diffuses deep into the formation farther away from the electrodes, and the streaming potential decreases. The rates of the initial increase and the subsequent decrease of the streaming potential are determined by the permeability of the skin, the thickness of the skin, and the permeability of the undamaged formation.
- Zone 2 streaming potential data recorded by all seven electrodes 118-8 through 118-14 in Zone 2 are shown alongside the pressure data in Figure 5.
- the Zone 3 streaming potential data are shown in Figure 6.
- the reservoir is clearly heterogeneous within each zone; individual streaming potential curves in Figure 5 and Figure 6 all have very different rise and decline rates, indicating large variations in permeability.
- measuring streaming potential with an array of electrodes yields significantly increased information relative to the information that can be gleaned from a single pressure buildup curve for each zone which would yield only the average permeability for that zone.
- the magnitude of the streaming potential is an indicator of the water fraction of flow, and it varies from electrode to electrode. As seen in Figure 5, there is little water production near electrode 118-13 (i.e., the streaming potential remains near 0 mV) , and in Figure 6, there is no or little water production near electrodes 118-16 and 118-17.
- Zone 1 The voltages of the Zone 1 electrodes are shown in Figure 7. Since Zone 1 is hydraulically isolated from Zone 2 and Zone 3 and the Zone 1 valve remained closed, the observed voltages were drifts in the electrodes. The drifts are of the order of less than one millivolt per day. Since the electrodes are steel centralizers exposed to the annulus fluid, drifts of such magnitude are expected.
- Zone 2 and Zone 3 valves were shut and Zone 1 valve was opened and remained open.
- the pressure transient and the streaming potentials resulting from that test are shown in Figure 8.
- the large streaming potential measurement and double peak associated with electrode 118-1 revealed a fracture.
- the significant variations in streaming potential rise times e.g., compare electrode 118-6 with electrode 118-5, indicated large variations in formation permeability along Zone 1.
- Electrode 118-1 revealed a fracture in the formation with high permeability
- electrodes 118-2 through 118-5 and electrode 118-7 indicated formation locations having medium permeability
- electrode 118-6 indicated a formation location of high permeability
- electrodes 118-8 through 118-10 and 118-14 indicated formation locations of medium permeability
- electrodes 118-11 and 118-12 indicated a formation location or mini-zone of low permeability.
- electrode 118-12 revealed a fracture in the formation.
- Electrode 118- 13 indicated a formation location with no water flow.
- Electrodes 118-15 and 118-18 through 118-20 indicated formation locations of high permeability
- electrode 118-21 indicated a formation location of medium permeability
- electrodes 118-16 and 118-17 indicated formation locations or mini-zone of no water flow.
- the streaming potential transients are computed from a forward model of a heterogeneous formation shown graphically in Figure 9a.
- the modeled response is shown in Figure 9b.
- the streaming potential recorded by an electrode placed in the high permeability region rises faster and decays faster than that the streaming potential recorded by an electrode placed in the low permeability region.
- this modeled response agrees with the data presented in Figures 5 and 6.
- the streaming potential transients are computed from a forward model of another heterogeneous formation shown in Fig. 9c.
- the streaming potential transient computed from a forward model shown graphically in Figure 9c supports the interpretation of the streaming potential recorded by electrode 18-12 ( Figure 5) ; i.e., that a fracture will produce a double peaked streaming potential transient response.
- Figs. 10 - 19 the use of streaming potential transient information is shown with respect to a vertical injection well 200 located in formation 205.
- the formation 205 includes a hydrocarbon reservoir with a location identified at between 1026 ft and 1047 ft.
- the well 200 includes a casing 209 around which electrical insulation 211 is provided.
- the casing, insulation and array are cemented in place by cement layer 217.
- the electrodes 218-1 through 218-16 are in contact with the cement 217 but not with the metal casing 209.
- the casing in order to produce hydrocarbons, the casing must be perforated with oriented perforations 219 so as not to damage the electrodes and the connecting cables (not shown) .
- the uphole injection pressure is shown in Figure 12.
- the valve had been shut for a long time.
- the injection pressure increased suddenly at the opening of the valve, and then periodically dropped and recovered as the pump was shut down for brief periods of time.
- the streaming potential transients sensed by the electrodes of primary interest inside the reservoir interval of interest are shown in Figure 13 and in an expanded time scale in Figure 14 (it being noted that electrode 218-12 failed and thus no data is shown for it) .
- the streaming potential transients clearly have two components: one component changes very quickly in response to pressure changes, and the other component changes slowly over a period of days.
- the fast component relates to water flowing into fractures with high permeability. The changes in the fast component in Figs.
- 13 and 14 are such that the streaming potentials decrease with increasing injection pressure and increase with decreasing injection pressure. This is expected since injection water carrying positive charges moves away from the borehole and away from the electrodes.
- the signs of the streaming potential of well 200 are opposite to those of the streaming potential transients shown with respect to well 100, as the data for well 100 was collected with water carrying positive charges moving into the borehole toward the electrodes during production.
- the slow component of the transient curve comes from water injection from the borehole directly into the rock matrix with low permeability, or from the cross-flow from the fractures into the rock matrix.
- the direct flow of injection water into the rock matrix is always away from the electrodes.
- the cross-flow from fractures into matrix is also away from the electrode if the electrode is situated directly at the fracture.
- the streaming potential recorded by such electrodes will decrease slowly as water moves into the matrix. If the electrode is at some distance away from the fracture, the cross-flow passes across the electrode. As a result, the streaming potential will either decrease slowly or increase slowly as water moves into the matrix, depending on the exact location of the electrode relative to the fracture.
- the data in Figures 13 and 14 can be interpreted as showing that electrode 218-5 is situated directly at a strong fracture, while electrode 218-9 is situated a little distance away from a fracture.
- Electrode 218-2 is located very close to the thin permeable sand adjacent a non-perforated portion of the casing. Yet, the streaming potential of electrode 218-2 reached a value of 150 mV, which is five times higher than the streaming potentials recorded by any electrode in the reservoir interval. This may be explained by understanding that the interval above the perforated interval had been fractured, presumably from a cement annulus (which was confirmed by the cement evaluation job) . Thus, the shapes of the streaming potential transients in this interval are different from those in the reservoir interval. In this interval, the streaming potential appears to be comprised of three components: fast, medium, and slow.
- a shale layer located between the reservoir and the thin sand layer is probably fractured. Flow through the fractures in the shale layer has a time scale in between the flow time scales of the sand and matrix.
- Fig. 17 the streaming potentials sensed by the electrodes 218-13 through 218-15 below the reservoir are seen.
- the voltages sensed by these electrodes are less than 1 millivolt. Thus, it can be concluded that there is very little injection water flowing below the reservoir interval .
- a qualitative interpretation of the streaming potential transient data may be made and summarized as shown in Figure 18.
- a fracture with cross-flow exists through a shale layer atop the reservoir; a fracture with cross-flow exists at 1028.55 feet (electrode #4); a fracture with cross-flow exists near 1037.55 feet (electrode #9); and a fracture with cross-flow exists at 1042.05 feet (electrode #11) (see Fig. ⁇ 13) .
- Fig. 18 The qualitative interpretation of Fig. 18 is supported by the forward model shown graphically in Figure 18a and the modeled response shown in Fig. 18b which show that the streaming potential from cross flows can either have the same sign or the opposite sign to that of the fracture flow.
- the modeled response successfully reproduced the observed data of electrode 218-9 of Figure 13 and electrode 218-2 of Fig. 15.
- Electrode 218-13 voltage had some noise spikes up to 100 microvolts.
- the noise spikes happened at a very short time scale, were unrelated to the surface stabilities of the electrodes, and were likely due to noise picked up on the wire 235 connecting the electrode and the surface electronics 233 (Fig. 10) .
- These noise spikes can be lessened or eliminated by better wiring and electronics, or by downhole electronics.
- the voltages of electrodes 218-13 through 218-15 correlated very well with the uphole pressure data.
- the opening of the valve 223 at 116.43 all three voltages decreased, and when the pump 221 stopped momentarily near day/time 116.8, all three voltages showed a small but visible peak.
- the correlation is very similar to those observed in the much larger voltages measured by electrodes located in the reservoir and in the interval atop the reservoir. Based on this information, it can be concluded that the electrode stability for the cemented electrodes is of the order of 10 micro-volts and signal levels of 100 micro-volts are adequate to determine reservoir properties of interest.
- the stability of the cemented electrode array 218 is at least one hundred times better than the exposed centralizer electrodes 118 shown with reference to well 100.
- the electrodes of the electrode array utilized to sense and measure streaming potential transients are preferably covered or coated with a semi-porous covering material (such as cement) , whether utilized as centralizers as shown with reference to a sand-screen completion or in other permanent installations, or when used in MWD or wireline applications as discussed hereinafter.
- a semi-porous covering material such as cement
- the semi-porous covering material should have a significant electrical conductivity but a very low permeability so that ions can reach the electrode to enable voltage measurements, but no new fluid reaches the electrode surface during the time period of measurement.
- the surfaces of the electrodes are in a stable chemical environment, which gives rise to measurement stability.
- a presently preferred semi-porous material is cement, although a semi-porous ceramic, clay, or other material could be utilized.
- liquid junction electrodes can be utilized, as the semi-porous plug of a liquid junction electrode stops fluid movement but allows ionic diffusion.
- a stable electrode allows the measurement of a transient over a longer period of time, thereby permitting an analysis deeper into the formation, and also permitting measurements at weaker signal levels.
- streaming potential measurements can be made of the formation (matrix) permeabilities and the effective fracture permeabilities along the well utilizing equations (9) through (11) as discussed above and by considering fractures as a thin medium with given permeability.
- the streaming potential measurements can be utilized to obtain real time monitoring of fracturing jobs. For example, when well 200 was fractured, the target was the middle reservoir interval of interest, and the fracturing of the upper interval was not desired. However, the injected water did not go where it was desired.
- a formation 305 is seen traversed by an open hole completed well 300 having a tubing 306 extending therein.
- An insulated sonde 311 is shown around the tubing with electrodes 318-1, 318-2... disposed on the insulated sonde 311.
- the tubing 306 is essentially just a conveyance means for moving the sonde 311 to desired locations.
- Other conveyance means which are preferably relatively solid, but somewhat flexible, could be utilized.
- a cased hole completion is shown in Fig. 21, with a formation 405 traversed by a well 400.
- the well includes an insulated tubing 406, and a casing having conductive electrode portions 418-1, 418-2, 418-3,... separated by electrically insulated portions 416 which are cemented into the well by cement 417.
- the metal casing serves as an electrode array with individual sections of the casing electrically isolated from one another.
- the casing sections may be regular casing sections connected by isolation joints, or specially designed casing sections made of two or more electrically isolated subsections.
- the electrodes 418 are in contact with the cement 417 and with the fluid inside the casing.
- the tubing 406 inside the well is metallic, the tubing is preferably electrically insulated or partially insulated.
- a tool and method for measuring streaming potentials while drilling a borehole is provided.
- a pressure difference between the formation and the borehole creates mud invasion and pressure transients, and thus, streaming potential transients.
- a streaming potential will exist if the mud contains a water fraction.
- Drilling tool 510 includes a drill bit 507 and electrodes 518-1, 518-2, 518-3..., 518-R (all preferably coated with a semi-porous covering such as cement) mounted on electrically insulated sections 511-1, 511-2, 511-3 of the drill pipe 515.
- the electrodes 518 move with the tool 510.
- different electrodes in the array will sense at different points in time the streaming potential transient at a fixed spatial point.
- the spacing between the electrodes 518 in the array and the drilling speed determines the temporal sampling rate of the streaming potential transient.
- the time at which electrode 518-2 is located at a particular previously measured by electrode 518-1 is dependent upon both the drilling speed and the distance between the electrodes.
- the top electrode 518-R is used as the voltage reference electrode, as it is farthest from the drill bit and will often arrive at locations in the formation when the streaming potential transient has already reached steady state values.
- wires connecting the electrodes, measuring electronics, and telemetry which are standard in the art, are provided in, on, or with the LWD tool 510 but are not shown in Figure 22.
- a processor 550 and associated data storage 560 are shown which are used to obtain answer products are shown in Fig. 22. It will be appreciated that the processor 550 and data storage 560 are applicable to the other embodiments as well, although the processor may utilize different forward and inverse models.
- the streaming potential measurements made are passive voltage measurements, which can be made in a highly resistive borehole by using high impedance electronics.
- the electrodes need to be as large as possible and placed as close as possible to the formation to reduce electrode impedance.
- the streaming potential information obtained by the tool and processed can yield various answer products . Since the streaming potential transients created by drilling will change rapidly with time for a formation with high permeability and slowly for formation with low permeability, with an inversion model that contains the mudcake built-up model, formation permeability of the invaded zone and the uninvaded zone can be obtained.
- a system for early detection of drilling fluid loss may be implemented.
- streaming potential will rise instantaneously as fluids rush into the formation.
- the changes in borehole pressure will be somewhat slower, since the borehole has a storage capacity. Noticeable fluid loss at the surface will happen much later.
- large changes in the streaming potential will be detectable long before the fractures becomes serious. Therefore, monitoring of the streaming potential measurements can be used for early detection of fluid loss.
- the streaming potential information can be utilized for the early detection of abnormal formation pressures. For example, if the formation pressure becomes higher than the borehole pressure, the signs of the streaming potential will reverse. This reversal of sign will be observable before sufficient amount of fluid has flowed into the borehole for the pressure kick to be observable. The build-up of the flow reversal may happen over a short but finite period of time as the abnormal pressure zone is being drilled. Any reversal of flow will be immediately observable in the streaming potential measurements. Therefore, streaming potential measurements have value in the early detection of abnormal formation pressure .
- a wireline streaming potential tool 610 is provided.
- the wireline tool 610 is shown suspended by a cable 611 in a borehole 600 (having mud cake 607) traversing a formation 605.
- the wireline tool 610 is provided with an insulated sonde 616 on which an array of electrodes 618-1, 618-2, 618-3... including a reference electrode 618 -R, and associated preferably high impedance voltage measuring circuits are provided.
- the electrodes are preferably coated with a semi-porous material such as cement.
- tool 610 includes one or more preferably retractable arms 631 on which one or more cutting edges 635 are mounted.
- the cutting edges 635 are designed to cut slits across the mudcake 607 as the wireline tool is moved through the borehole.
- the cutting edges may be made with a polycrystalline diamond compound (PDC) . Because there is a large overbalancing pressure difference between the formation and the borehole (most of the pressure difference exists across the mudcake) , after the cutting edges 635 slit the mudcake 607, a new mudcake will quickly build up in the slit to stop the fluid flow. In the mean time, a pressure transient has been created in the formation 605. In wells drilled with oil-based mud, streaming potential transients will be created if the mud has a water fraction.
- the electrodes 618 move with the tool 610 in a continuous logging mode. Different electrodes in the array sense the streaming potential transient at a fixed spatial point. The spacing between the electrodes in the array and the logging speed determines the temporal sampling rate of the streaming potential transient.
- the top electrode 618-R is used as the voltage reference electrode, as it is farthest from the cutting edges and no streaming potential transient has yet been created there. Wires connecting the electrodes, measuring electronics, and telemetry are provided but not shown in Figure 23. As previously mentioned, the arms 631 are preferably retractable.
- a gamma ray detector 640 is provided in order to help align data from repeat runs.
- streaming potential measurements are passive voltage measurements which can be made in a highly resistive borehole by using high impedance electronics.
- the electrodes are preferably relatively large (by way of example and not limitation, twelve inches by two inches) and are preferably placed on articulated pads (not shown) or on a skid sonde to insure close contact with the formation.
- the spurt loss from the cutting of mudcake is likely to happen over a short time period compared with the time needed for the pressure transient to diffuse beyond the invaded zone. If that is the case, then the source of the streaming potential transient created by the cutting of mudcake can be treated as a delta function of time.
- the inversion of the data for a short period of time can be carried out without any input from the mudcake build-up model. After the spurt loss, the mudcake will build back up by a static process. The thickness of the mudcake will increase with the square root of time.
- the inversion of streaming potential data over a longer period of time with a mudcake that increases with the square root of time is still quite robust.
- the mud invasion is a continual process even with a good mud system.
- the streaming potential transients created by the mud invasion are likely to be measurable when the logging time is not too far away from the time when the well is drilled or reamed.
- the tool shown in Figure 23 with the cutting edges retracted (or without the arms and cutting edges) can record the streaming potential created by the previous drilling and/or reaming, and the continual mud invasion. In such a situation, a model for a long measuring period and a mudcake build-up will be utilized for interpreting the streaming potential data collected.
- the wireline streaming potential tool can be used with appropriate modeling and inversion to provide measurements of formation permeability in the invaded zone, beyond the invaded zone, and in the far zone, continuously along the borehole.
- the transients acquired over long periods of time without the cutting blade will help to determine the permeability in the far zone.
- Figure 23d shows the dependence of the streaming potential on the thickness of the invaded zone. Equation (4) shows that the time it takes for the pressure transient to diffuse through the invaded zone depends on the invaded zone thickness ⁇ and invaded zone permeability : through the combination ⁇ Ik . Equation (8) shows that in approaching the steady state, the streaming potential from the invaded zone depends on ⁇ and A; through the combination A lk . The difference between these two combinations suggests that the thickness and the permeability of the invaded zone can be individually determined by inversion.
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Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
EP05769373A EP1756622A2 (en) | 2004-06-18 | 2005-06-17 | Methods and apparatus for measuring streaming potentials and determining earth formation characteristics |
CA002570049A CA2570049A1 (en) | 2004-06-18 | 2005-06-17 | Methods and apparatus for measuring streaming potentials and determining earth formation characteristics |
MXPA06014506A MXPA06014506A (en) | 2004-06-18 | 2005-06-17 | Methods and apparatus for measuring streaming potentials and determining earth formation characteristics. |
Applications Claiming Priority (8)
Application Number | Priority Date | Filing Date | Title |
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US10/871,856 | 2004-06-18 | ||
US10/872,112 US7243718B2 (en) | 2004-06-18 | 2004-06-18 | Methods for locating formation fractures and monitoring well completion using streaming potential transients information |
US10/871,856 US7233150B2 (en) | 2004-06-18 | 2004-06-18 | While-drilling apparatus for measuring streaming potentials and determining earth formation characteristics |
US10/871,854 | 2004-06-18 | ||
US10/871,446 US7520324B2 (en) | 2004-06-18 | 2004-06-18 | Completion apparatus for measuring streaming potentials and determining earth formation characteristics |
US10/871,446 | 2004-06-18 | ||
US10/871,854 US6978672B1 (en) | 2004-06-18 | 2004-06-18 | Wireline apparatus for measuring steaming potentials and determining earth formation characteristics |
US10/872,112 | 2004-06-18 |
Publications (2)
Publication Number | Publication Date |
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WO2005124395A2 true WO2005124395A2 (en) | 2005-12-29 |
WO2005124395A3 WO2005124395A3 (en) | 2006-07-06 |
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PCT/IB2005/002468 WO2005124395A2 (en) | 2004-06-18 | 2005-06-17 | Methods and apparatus for measuring streaming potentials and determining earth formation characteristics |
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Country | Link |
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EP (1) | EP1756622A2 (en) |
CA (3) | CA2793786A1 (en) |
MX (1) | MXPA06014506A (en) |
RU (1) | RU2012143734A (en) |
WO (1) | WO2005124395A2 (en) |
Cited By (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10012064B2 (en) | 2015-04-09 | 2018-07-03 | Highlands Natural Resources, Plc | Gas diverter for well and reservoir stimulation |
US10344204B2 (en) | 2015-04-09 | 2019-07-09 | Diversion Technologies, LLC | Gas diverter for well and reservoir stimulation |
WO2019217762A1 (en) * | 2018-05-09 | 2019-11-14 | Conocophillips Company | Measurement of poroelastic pressure response |
US10982520B2 (en) | 2016-04-27 | 2021-04-20 | Highland Natural Resources, PLC | Gas diverter for well and reservoir stimulation |
US11727176B2 (en) | 2016-11-29 | 2023-08-15 | Conocophillips Company | Methods for shut-in pressure escalation analysis |
CN117348090A (en) * | 2023-10-13 | 2024-01-05 | 山东科技大学 | Coal spontaneous combustion underground detection system and method based on natural potential method |
Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
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US2728047A (en) * | 1952-06-13 | 1955-12-20 | Schlumberger Well Surv Corp | Methods and apparatus for logging spontaneous potentials in wells |
US3268801A (en) * | 1963-04-30 | 1966-08-23 | Texaco Inc | Apparatus having a pair of spaced electrodes for measuring spontaneous potentials in a well bore while drilling |
US5103178A (en) * | 1990-09-11 | 1992-04-07 | Louisiana State University And Agricultural And Mechanical College | Method using a pluraliyt of electrode, including a reference electrode, for recording a spontaneous potential curve in a borehole while drilling |
-
2005
- 2005-06-17 MX MXPA06014506A patent/MXPA06014506A/en active IP Right Grant
- 2005-06-17 EP EP05769373A patent/EP1756622A2/en not_active Withdrawn
- 2005-06-17 WO PCT/IB2005/002468 patent/WO2005124395A2/en active Application Filing
- 2005-06-17 CA CA2793786A patent/CA2793786A1/en not_active Abandoned
- 2005-06-17 CA CA002570049A patent/CA2570049A1/en not_active Abandoned
- 2005-06-17 CA CA2794316A patent/CA2794316A1/en not_active Abandoned
-
2012
- 2012-10-12 RU RU2012143734/28A patent/RU2012143734A/en not_active Application Discontinuation
Patent Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2728047A (en) * | 1952-06-13 | 1955-12-20 | Schlumberger Well Surv Corp | Methods and apparatus for logging spontaneous potentials in wells |
US3268801A (en) * | 1963-04-30 | 1966-08-23 | Texaco Inc | Apparatus having a pair of spaced electrodes for measuring spontaneous potentials in a well bore while drilling |
US5103178A (en) * | 1990-09-11 | 1992-04-07 | Louisiana State University And Agricultural And Mechanical College | Method using a pluraliyt of electrode, including a reference electrode, for recording a spontaneous potential curve in a borehole while drilling |
Cited By (11)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10012064B2 (en) | 2015-04-09 | 2018-07-03 | Highlands Natural Resources, Plc | Gas diverter for well and reservoir stimulation |
US10344204B2 (en) | 2015-04-09 | 2019-07-09 | Diversion Technologies, LLC | Gas diverter for well and reservoir stimulation |
US10385258B2 (en) | 2015-04-09 | 2019-08-20 | Highlands Natural Resources, Plc | Gas diverter for well and reservoir stimulation |
US10385257B2 (en) | 2015-04-09 | 2019-08-20 | Highands Natural Resources, PLC | Gas diverter for well and reservoir stimulation |
US10982520B2 (en) | 2016-04-27 | 2021-04-20 | Highland Natural Resources, PLC | Gas diverter for well and reservoir stimulation |
US11727176B2 (en) | 2016-11-29 | 2023-08-15 | Conocophillips Company | Methods for shut-in pressure escalation analysis |
WO2019217762A1 (en) * | 2018-05-09 | 2019-11-14 | Conocophillips Company | Measurement of poroelastic pressure response |
US11209558B2 (en) | 2018-05-09 | 2021-12-28 | Conocophillips Company | Measurement of poroelastic pressure response |
US11500114B2 (en) | 2018-05-09 | 2022-11-15 | Conocophillips Company | Ubiquitous real-time fracture monitoring |
US11921246B2 (en) | 2018-05-09 | 2024-03-05 | Conocophillips Company | Measurement of poroelastic pressure response |
CN117348090A (en) * | 2023-10-13 | 2024-01-05 | 山东科技大学 | Coal spontaneous combustion underground detection system and method based on natural potential method |
Also Published As
Publication number | Publication date |
---|---|
RU2012143734A (en) | 2014-04-20 |
CA2793786A1 (en) | 2005-12-29 |
CA2570049A1 (en) | 2005-12-29 |
WO2005124395A3 (en) | 2006-07-06 |
MXPA06014506A (en) | 2007-07-09 |
CA2794316A1 (en) | 2005-12-29 |
EP1756622A2 (en) | 2007-02-28 |
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