Down-hole tool and method for providing images of earth formations on a microscopic scale

Abstract: Images of rock formations below the earth's surface can be obtained on a microscopic scale. A borehole tool uses a seal to isolate an interval of the formation from borehole fluids which are outside the seal. A probe of the toot engages a wall of the formation and then draws formation fluid from the formation into the interior of the tool. The tool then produces an optical image of the formation which indicates rock texture. The seal can comprise a pad, inflatable packers, compressional packers, or cement plugs. The images of the formation can be obtained with electro-optic imagers such as charge-coupled devices (CCD) or a camera operating in the visible and/or near infrared range, or with ultrasonic transducers operating in the sub-MHz to mid GHz range, for example. The near infrared range provides an optical image of the formation through opaque fluids such as oil based muds or oil itself.

Description: Field of the Invention The invention concerns imaging earth formations. More specifically, the invention concerns imaging an interval of a rock formation below the earth's surface on a microscopic scale. Background of the Invention Knowledge of rock texture is often crucial in characterizing a hydrocarbon reservoir in an earth formation. Rock texture, meaning the shapes and sizes of grains, the matrix and pore structure, for example, greatly effect porosity and permeability of the formation. Until now, knowledge of rock texture has been obtained through labor intensive studies based on core analysis. This analysis involves taking core samples of the formation, bringing the samples to the surface, then cutting or thin-sectioning the samples for examination under optical microscopes. Currently, micro-resistivity measurements can provide an image of a borehole wall. See U.S. Patent No. 5,038,378 to Chen, for example. Also, optical spectroscopic analysis can provide information about the borehole wall. See U.S. Patent No. 4,994,671 to Safinya et al. for example. Television and still cameras have been proposed for viewing boreholes through transparent slugs of fluid using visible or near infra red light. See U.S. Patent No. 2,953,979 to Rosene et al. Video cameras have been proposed for producing an image of a borehole wall or casing. See U.S. Patent No. 5,134,471 to Gendron et al. and 5,140,319 to Riordan, for example. There exists a need, however, for a technique for imaging the borehole wall of an earth formation at an improved spatial resolution to further characterize rock texture of the borehole wall through formation fluids such as filtrate water, mud, and oil. U.S. Patent No. 4,860,581 to Zimmerman et al. discloses a multiprobe module for anisitropic permeability and vertical reservoir tests useful in the present invention. U.S. Patent No. 4,696,903 to Owen relates to well logging and discloses a means and a method for providing a direct visual indication of the presence of a predetermined constituent of an earth formation. Further, U.S. Patent No. 3,992,095 to Jacoby et al. discloses an optics module for use in borehole stress measuring instruments. Summary of the Invention The invention concerns a method and apparatus for imaging an interval of a rock formation below the earth's surface on a microscopic scale. In addition, the invention concerns a method and apparatus for characterizing properties of an earth formation. The invention involves obtaining through formation fluids a first signal comprising a two-dimensional representation of a portion of a formation, wave energy having been reflected off the portion of the formation to produce the first signal; and characterizing a formation property based on the first signal. According to one embodiment, the invention involves an apparatus and method involving a borehole tool for obtaining data concerning formation properties. The invention involves isolating an interval of the formation from borehole fluids; drawing formation fluid from the isolated interval of the formation; producing wave energy which reflects from the isolated interval and receiving the energy, and producing signals representative of a portion of the isolated interval of the formation. In another embodiment, the signal represents rock texture of the formation. According to another embodiment, the invention concerns a downhole tool for obtaining data regarding formation properties. The tool comprises a sampling means having an inlet for providing fluid communication between the formation and the interior of the tool; a seal mounted adjacent the inlet to isolate an interval of the formation from borehole fluids located beyond the seal; and a pump for drawing fluid from the formation through the inlet of the sampling means; and a means for producing a signal comprising a two-dimensional representation of a portion of the isolated interval of the formation. Another embodiment involves indicating a property of a formation. This involves producing substantially near infrared (NIR) light such that the NIR light passes through opaque formation fluid in a borehole to illuminate a surface in the borehole; receiving the NIR light which reflects from the surface in the borehole and through the opaque formation fluid; and producing a signal in response to the received NIR light, the signal comprising a two-dimensional representation of the surface in the borehole and indicating a property of the formation. The seal can comprise the probe itself, or a pad which surrounds the probe and is forced against the borehole wall. Packers along the length of a borehole tool can also isolate an interval of the borehole wall. Such packers comprise inflatable packers, compressional packers, or cement plugs, etc., which, when placed in the borehole, isolate one interval of the formation from another. The formation intervals can be imaged with electro-optic, charge-coupled devices (CCD) or a camera operating in the visible and/or near infrared range, or with ultrasonic transducers operating in the sub-MHz to mid GHz range, for example. Furthermore, in coiled-tubing applications, production logging applications, or logging-while-drilling applications, surface in a borehole, such as a borehole wall or casing, can be imaged through formation fluids such as gas, water, water filtrate, mud, or oil. Brief Description of the Figures Figure 1a-b shows a schematic drawing of a prior art borehole tool for extracting samples from an earth formation. Figure 2 shows a schematic of an apparatus for making representations of a borehole wall, which is carried by the tool of Figure 1. Figure 3 shows the optical density spectrum of borehole fluid samples. Figure 5a and 5b shows digitized microscopic NIR images. Figure 7 shows an experimental set-up. Figures 9a-b show microscopic images of a berea rock surface. Figures 13a-c illustrate engagement of a probe with a rock surface. Figures 14a-b show microscopic images of berea sandstone with two muds. Detailed Description of the Invention Generally, the immediately following text describes transporting fluids at a selected rate out of an earth formation through a probe and into a borehole tool, and then imaging a rock formation surface with an electro-optical device in the probe. Figures 1a-b shows at A a schematic drawing of a borehole tool for extracting samples from an Earth formation and making pressure measurements useful in calculating formation permeability. As discussed in U.S. Patent No. 4,860,581 to Zimmerman et al., such a borehole tool includes a hydraulic power module C, a packer module P and a probe module E. The hydraulic power module C includes a pump 16, reservoir 18, and a motor 20 and low-oil switch 22 which connect to control the pump 16. A hydraulic fluid line 24 connects to the discharge of pump 16, runs through hydraulic power module C and into adjacent modules P and E (or F) to provide hydraulic power. Another hydraulic fluid line 26 extends from probe module E back to the hydraulic power module C and terminates at reservoir 18. A pump-out module M expels unwanted samples into the borehole by pumping a flow line 54, or to pump in fluid from the borehole to set or inflate straddle packers 28 and 30. The set straddle packers 28 and 30 hydraulically seal and isolate an interval of the formation from fluids which are present in the borehole beyond the packers 28 and 30. In this way, the borehole tool can examine formation fluids: those fluids found within the formation and beyond the borehole wall. Alternatively, hydraulic fluid from pump 16 can inflate or deflate the straddle packers 28 and 30. Straddle packers are described further in US Patent No. 4,860,581. The probe module E has a probe assembly 10 for obtaining formation fluid samples to conduct isotropic permeability tests, for example. A probe actuator 40 selectively moves the probe assembly 10 relative to the borehole tool. A probe frame 46 is surrounded by a seal 48 which comprises a pad of compressed rubber, for example. The seal 48 is movable relative to the borehole tool A and the probe 46 is movable relative to the seal 48. As such, the seal 48 initially contacts the borehole wall. Extending seal 48 brings the probe 46 adjacent the borehole wall. To actually take a sample from the formation, it is necessary to insert the probe 46 into the formation, through mudcake covering the borehole wall. Accordingly, the borehole tool A operates so that, when the flow line 24 aligns with the flow line 44, the probe 46 moves relative to the seal 48 and protrudes into the formation. Probes 12 and 14 operate in a similar way. A multiprobe module F can be added for anisitropic permeability and vertical reservoir tests, as discussed in US Patent No. 4,860,581 to Zimmerman et al. Pressure module B, fluid analysis module D, and flow control module N are discussed in detail in US Patent No. 4,860,581. Having set packers 28 and 30 to isolate an interval of the formation, the probe 46 can be set to draw fluids from the Earth formation. A sample flow line 54 extends from the outer periphery 32 between the packers 28 and 30, through adjacent modules and into sample modules. (see US Patent No. 4,860,581, for example). The vertical probe 46 and the sink probe 14 permit entry of formation fluids into the sample flow line 54. When taking initial samples, downhole optical spectroscopic analysis indicates that the first fluid drawn is visible because it is usually contaminated with mudcake and filtrate. The pumpout module M can be used to purge such initial samples. According to this description, the borehole tool continues to draw formation fluid through the sample line 54, Subsequent samples change from the contaminated fluid to filtrate water, substantially, before again changing to produced oil. When the continuously drawn formation fluid is water, an image of the borehole wall can be produced using visible light. This image reveals the rock texture of the formation. Alternatively, even when the continuously drawn formation fluid is substantially oil-based mud or oil itself, an image of the borehole wall can also be produced using near infrared radiation. This image also reveals the rock texture of the formation. Such images of the formation have a 5-micron resolution, approximately, Scales of textural features of rocks are on the order of 10 microns or lower. The images are converted to electronic signals for transmission up the borehole for display or for interpretation to characterize a formation property. Different devices for producing downhole images which indicate rock texture are described below. Figure 2 shows a schematic of a microscopic imaging module 100 in borehole tool like A of Figure 1. The probe module 10 of the tool A of Figure 1 is modified to incorporate an optical imaging device within the probe module, which is part of the flow line 102. The schematic shows a retractable probe 104 that makes a pressure seat with the borehole wall 106. Extended with the probe 104 is a retractable optics window 108 and fiber optic light guide I 10. The fiber light guide I IO is connected to a light source 112 for illumination of the borehole wall 106. The light source 112 may be a tungsten halogen bulb or narrow band high intensity light emitting diode or laser that is matched to the responsivity of the camera detector. The light source may be a continuous or flash source. The optics window 108 is used as a view window and pressure seal for subsequent optics. The flow line 102 and optics path diverge into two paths. The flow line 102 continues for use in other tool modules. The optics path is linked to a camera, light source, and its associated electronics, described below. Alternatively, the optical assembly of Figure 2 can be assembled as part of the tool of US Patent No. 4,860,581 between two packers. Or, the optical assembly of Figure 2 can be assembled as part of a borehole production tool, a coiled tubing system, or logging-while-drilling tool to directly view a borehole surface, such as a borehole wall or borehole casing through clear or opaque formation fluids present in the borehole. Such formation fluids include water, water filtrate, mud, oil, and/or gas. In production logging, the optical assembly can be sealed in a housing and lowered into a borehole by a cable or pushed through coiled tubing, for example. For coiled-tubing applications, the optical assembly can be sealed in a housing and pushed to an interval of a formation, between double packers (if needed) which isolate the interval of the formation. In logging-while-drilling applications, the optical assembly is mounted behind a window in a drill collar. A window in a drill collar is described in US Application Serial No. 08/402,680 to Mullins, et al. Relay optics 114 includes a lens system coupled with a coherent fiber optic bundle or may be constructed solely from lens optics. Shown in the schematic is a right angle prism 116 and a lens element 118 or elements (such as mirrors or other reflectors) that route the optical path by 90 degrees and magnify and relay the image of the borehole wall 106 to a camera 120. The lenses of the x-clay optics are chosen to provide a magnified image of the borehole wall to the camera's detector plane via the relay optics. This lens module has an adjustable zoom (magnification) and focus feature. The camera 120 comprises the camera head 122, a dimensional (n x n pixels) detector in the camera head, camera controller, and processing electronics. The camera detector is either a silicon-based detector and/or InGaAs-based detector, sensitive in the NIR. The output of such a camera is a signal representative of a 2-dimensional image comprising, for example, a digital video output. The camera has a camera controller that provides electrical and timing signals to the camera detector head. This module allows for the transfer of electronic signal from the n x n pixels that make up the camera detector to the image processing electronics. The camera controller comprises focus and zoom controls. The processing electronics 126 modifies any image, or any signal comprising a two-dimensional representation of a formation interval, acquired by the camera head making it suitable to be transmitted uphole to standard data controllers and the wireline cable or transmits signals representative of a feature of the received formation interval. This device may perform functions such as removing background 2-D signals, correcting for uneven pixel (detector) responsivity or 2-D signals enhancement via signal processing techniques. CCD The electro-optic imager of Figure 2 can comprise a charge-coupled device (CCD). CCD's rely on well-established semiconductor architecture comprising a metal oxide-silicon (MOS) capacitor. The capacitor consists of a silicon substrate, a thin layer of silicon dioxide, and a thin metal layer gate on the silicon dioxide layer. Such silicon based imagers transform an optical image, or a spatial distribution of radiation, into a time-distributed voltage signal. CCD's cover the visible band and the shorter wavelengths of the near infrared band (0.4 to 1.1 micron). Commercially available CCD's and frame grabber hardware, see the example, operate with little light and have enough dynamic range to provide a minimum of 256 shades of grey. In addition to MOS-type CCD'S, the electro-optic imager can comprise InGaAs-based devices or InGaAs-silicon-based devices in a 2-D array, as discussed below. The choice of electro-optic imager for operating in the visible light range depends upon the fluid covering the rock surface. For instance, in the case of a fractured surface of sandstone with a few millimeters of tinted mud filtrate between the imager's lens and surface of the rock, which may exist in the borehole when clear fluids, such as mud filtrate, are clouded by suspended sediments and flow into a formation testing probe. If the optical path between the rock formation and the detector is not clear, another possibility is to inject clear fluids into the formation as described in US Patent No. 5,269,180 to Dave et al. In both cases, the size and shape of each individual grain can easily be characterized from such a high contrast image. VISIBLE/NEAR INFRARED The electro-optic imager of Figure 2 can comprise a camera operating in the visible/near infrared spectrum to image through opaque formation fluids. To image rock samples in a borehole environment would involve imaging through opaque borehole fluids (water filtrate, light to heavy crude oils). We have tested a visible-near infrared (VIS-NIR) camera and have found that we can image through such opaque formation fluids. This technique requires a light source and a near IR detector operating at a suitable wavelength and resolution. The problems of mudcake removal through an open window in a continuous or stationary fashion is addressed below. We first examined the transparency of borehole fluids by imaging through a separate 2.5 mm thick samples, one representative of a dark heavy crude oil (a Strata oil sample) and the other of clear water. Figure 3 shows the optical density spectrum of these two samples. In the visible range, the representative dark heavy hydrocarbon has an optical attenuation greater than clear water by 6 orders of magnitude. In the NIR, oil has a small absorption peak near 1.7 mm, and the light absorption due to electronic transitions above 0.9 mm is not nearly as large as in the visible. Also in the near infrared, water has two rather large molecular absorption features near 1.4 and 2.0 mm, but is fairly transparent elsewhere. Therefore, both oil and water have windows of transparency that can be utilized so that the integrated light signal below 2.0 mm should provide enough light for a usable image. Alternatively, a high intensity light source in a narrow band in the NIR (laser or LED, for example) may be used. Experiments showed the feasibility of imaging through oil, as well as the limitations on the image contrast due to the presence of oil. Figure 5 shows a) an image of an unpolished surface with no oil sample and visible light, and b) an image of the same rock surface with NIR light through the same crude oil sample. Figure 5b is the resulting digitized microscopic NIR image through a 2.5 mm sample of Strata oil. Comparable images taken in the visible spectrum produce no image at all. Although the oil acts as a filter, we illuminated the rock sample with NIR light between 1.0 mm and 2.0 mm. NIR is generally defined as 0.75 to 3.0 microns. The preferred range of NIR is generally above visible wavelengths to about 2.2 microns. The grain sizes for this sample are large, approximately 300 microns in diameter. For this application, spatial resolution is a trade off between magnification and field of view. For the relatively low magnification of this image, the high contrast image resolution, verified independently, is 12 microns. An image of similarly high quality was also captured through a 2.5 mm water sample. For reference, Figure 5a shows the same rock imaged with visible light and no oil present. We see that the images in Figures 5a and 5c are remarkably alike. We can, therefore, draw the conclusion that the opacity of borehole fluid will not degrade imaging in the NIR. For wireline application, a new indium gallium arsenide (InGaAs) detector 2-D array offers silicon performance, but for infrared applications where near-infrared detection had been made with detectors of lead sulfide (PbS), germanium (Ge), or indium antimonide (InSb). The advantage of InGaAs stems from its direct energy bandgap structure and its tunable alloy composition which covers the spectral range of 0.9 to 1.7 microns. An InGaAs detector yields the largest integrated signal over a wide range of fluid color and best handles color contrast between oil and water at large standoffs. This detector does not have the drawback of PbS arrays with their slow speed or photodiode arrays such as InSb which required cryogenic cooling and were quite expensive. With its speed, temperature and sensitivity advantages and an expected drop in costs, a InGaAs 2-dimensional array could be used for imaging of near-infrared wavelengths of light in an open hole environment. Also, InGaAs layered over silicon will yield a visible-near infrared (VIS-NIR) detector. The NIR portion of silicon alone will yield a detector suitable for less opaque formation fluids. ULTRASONIC The electro-optic imager of Figure 2 can comprise a scanning acoustic microscopy imager, such as an ultrasonic imager, for example. Scanning acoustic microscopy is a high resolution imaging technique for characterizing surface and subsurface elastic properties of an object under examination. Mechanical motion drives a focused acoustic transducer perpendicular to the surface of the object. The scanning acoustic device is in a reflection mode. That is, a short pulse excites the transducer and multiple echoes in the system are time-separated. The arrival time of the echo indicates distance of the corresponding reflector from the acoustic transducer. The magnitude of the first return echo provides an estimate of the reflectivity of the object Data acquisition is conducted continuously while the scanner is in continuous motion. Scanning over an object builds up an image representing the reflectivity of the object, point-by-point. Acoustic microscopy can span sub-MHz to the mid-GHz range, employing a variety of coupling fluids. For low GHz operation in water, acoustic microscopy achieves spatial resolution similar to optical microscopy. Using an acoustic imager, we have seen quartz grains, which are fairly course in the range of 50 to 250 microns, revealing well-defined boundaries. In this case, the acoustic image may show a better contrast than the optical image. Surface roughness can have a significant negative effect on the reflectivity image and accurate inversion of true acoustic impedance. EXAMPLE Below, we describe experimental investigation of texture imaging while sampling mud filtrate through a 1cm diameter probe pressed against a rock surface. We have found that qualitative predictions of the physical state of the mudcake can be made while the fluid mixture is withdrawn. The key idea is to show that stationary sampling provides mudcake removal and leaves only formation fluids (clear or opaque to the photodetector) between the rock sample and an array camera. Knowledge of the fluid states and mudcake removal process in the probe will provide the necessary information for the design of the optical hardware necessary to image formation rock surfaces. Figure 7 shows a pressure cell and schematic of the experimental setup. Experiments were carried out in an X-ray transparent cell made of plexiglas and epoxy and rated 2758 KPa (400 psi). The porous solid was a Berea sandstone with a 100 md permeability and a 0.18 porosity. The rock sample was 10x10x5 cm and each flat face of the sample was sealed with epoxy. The one surface exposed to fluids was left unsealed. A curved plexiglas chamber which extended over the entire surface, was attached to one end. The chamber contained mud and was maintained at hydrostatic pressure so that a mudcake could form. A 1cm diameter tube which served as a probe, was mounted at the center of the vessel as indicated Figure 7. An actuator (not shown in Figure 7) was used to slide and set the probe against the rock surface. An opening in the epoxy on the other face of the rock opposite to the probe is also visible in the CT scanner X-ray attenuation image of the pressure cell setup. It provides a communication path for the mud filtrate between the rock formation fluid and a reservoir initially contain For imaging purposes, a Titan G series miniature 4 mm diameter horoscope, with a 365 mm length, was inserted into the probe. The horoscope is made of a series of miniature lens utilizing a rod-lens relay concept. Such a system of relay lenses is effective when it is desired to carry an image through a relatively tong distance and the available space limits the diameter of the lenses which can be used, The illumination uses cold light fibre-optic: the light is brought to the front of the horoscope by a series of glass fibres completely surrounding the front objective lens which allows the light source to be located away from the boroscope. The intensity of light was controlled by a rheostat to maximize light output. The optical assembly was mounted inside the probe with the focusable eyepiece isolated from the fluid by a set of pressure seals. Figure 9 shows a comparison between a) an optical image acquired with a Titan horoscope and its internal fiber-optics illumination and b) the same image acquired with an external light source. Figure 9a shows the microscopic image of the berea rock surface. The light ring is due to an internal reflection at the inner wall of the high pressure window. The light can be brought to the front of the horoscope from a point to its side with a proper angle to avoid this reflection as indicated by Figure 9b. The focusing eyepiece on the horoscope was combined with a video adapter to accommodate a video CCD camera. For our application, we used a SONY XC-75 with a CCD composed of 768x494 effective picture elements (horizontal/vertical) which correspond to a cell size (or pixel) of 8.4x9.8 microns. The output of the camera consisted of a horizontal resolution of 570 TV lines with 485 vertical effective lines. The Neotech Image Grabber hardware allows one video image to be grabbed and saved; the resulting image data is a disk file composed of 640x480 pixels (NTSC format) and 256 grey levels per pixels (8 bits). Figures 1,2 and 9 are digitized outputs at different magnification from this system. The mud used was a conventional dispersed bentonite water base mud maintained at approximately a pH of 10 by the addition of caustic soda, dispersed with the proprietary agent New-thin made by Milchem. One batch of mud was prepared for these experiment in a 40 litter vessel using cold tap water. Bentonite was added to a caustic soda solution to a concentration of 65 g/l with a few drops of New-thin deflocculating agent. The biocide Aquatreat DNM-30 was also added. The whole mixture was agitated for about four hours with a high shear Silverson mixer. The mud was allowed to hydrate and the pH was adjusted. The mud was left to age overnight and was used for several experiments over a period of one month. This method of preparation gives reasonable reproducible mud rheology. After mounting the epoxied rock sample onto the filtration cell, the apparatus was pressurized by compressed nitrogen fed to a mud reservoir of 2 litre total capacity. A maximum working pressure of 2758 KPa (400 psi) was achieved due to the pressure cell rating. A schematic of the mud circulation set-up is also shown in Figure 7. Mud is flooding from the reservoir to the cell through an opening on the side of the pressure chamber and is driven out of the cell through the probe. A set of valves allows to fill the cell and evacuate the mud through the probe. Mudcake build up at the rock interface occurred under static filtration while the system was shut in with a constant pressure of 2758 KPa (400 psi) in the accumulator. The estimated post mortem filter cake thickness was 15 mm. Preparation for the experiment began by saturating the epoxied Berea rock sample with distilled water. This was done under vacuum in a tank, resulting in the sample being fully immersed in water. The pressure cell was then assembled after positioning the sample and mud started to be injected through the tubing and circulated through the probe. Due to the mud reservoir maintaining the mud column at a constant 2758 KPa (400 psi) and no resistive pressure in the rock sample, a mudcake formed at the rock interface. Filtrate fluid loss was collected for 27 hours. Then the rock sample pressure was raid to 689 KPa (100 psi) by connecting a pressurized tank filled with distilled water while maintaining the mud column at 2758 (400 psi), leaving the static mudcake in place between the rock sample and the mud column. Figure 13a-f are schematics (a-c) of three different experimental conditions with the corresponding digital video images (d-f). The mud is opaque in the visible range (a) and the grains are visible when the formation fluid is clear (b). During the imaging experiment, a sequence of images was collected as the actuator was used to position the probe until it touched the surface of the rock sample. Figure 13a shows a schematic of the probe in communication with the mud and the associated frame of the digitized video signal. As expected the image is opaque. When the probe was brought in contact with the rock surface, (Figure 13b), a communication path was established with the formation fluid. To remove the mudcake and clear the internal part of the probe, the purge located at the other end of the probe was open to atmospheric pressure. The rock sample was maintained at a pressure of 689 KPa (100 psi), allowing the formation fluid to flow. In this example, we found it was not necessary to use a sealing packer or selaing pad to isolate an interval of a formation. To prevent the surrounding mud fluid, at 2758 KPa (400 psi), from flooding the probe, we relied on the bridging and clogging effect of the small particles suspended in the fluid to create the hydraulic seal between the probe and the formation (Figure 13b and c). For the clogging ability of the mud fluid particles to effectively isolate the interior of the probe, the gap between the tip of the probe and the formation wall must be calculated to be smaller than a specified value which depends on the size of the largest particle in the fluid. The resulting seal created by this clogging effect eliminates the need to mount a packer seal around the tip of the probe. Furthermore, replacing a packer-probe assembly by a stand alone probe provides an experimental simplification depending on the roughness of the rock sample. It has been shown that a set of particles in the size range 0-12 microns could bridge (clog) gaps with widths of about 30 times the largest particle size assuming that there is approximately a 10% volume fraction of solids in the mud fluid. For a particle size range of 150-200 microns, the gap width that can be clogged reduces to about 4 or 5 times the size of the largest particle size. The maximum gap possible between the probe tip and the well bore wall depends on these criteria. The particle size distributions of five typical drilling muds by MudTech vary from I micron, which is typical for bentonite particles, to 200 microns. Since drilling fluids contain particles as large as 200 microns (drilling cuttings may be larger), the gap between the tip of the probe and the borehole wall can be on the order of one-half millimeter. If the gap is too wide, mud invades the probe and prevents imaging of the rock surface. Refer to Figure 13b showing a schematic of the experimental condition. Filtrate and formation fluids are sampled under a 689 KPa (100 psi) differential pressure by opening the purge mounted on the back of the probe shown in Figure 7 while the probe is set against the rock formation. This pressure differential causes the break down of the mudcake seal. Providing that clogging effects at the sampling probe exist, the digital video image of the rock wall shown in Figure 13b was unchanged for the duration of the sampling. This experiment was successfully carried out several times with the same rock sample, but different muds. Figure 14 shows digital images of Berea sandstone grains while experimenting with two distinct muds. The probe is in contact with the rock sample while the bridging effect seals off the mud and the mudcake is moved by filtrate fluid. These experiments produced images similar in quality to those of Figure 14. That is a clear indication that the entire probe area was open to flow, that clogging effects indeed sealed off the mud and that the mudcake could be cleaned up with at least 689 KPa (100 psi) differential pressure. It also demonstrates that individual grains which composed the rock surface are clearly visible. DATA TRANSMISSION A typical single-frame, digitized image of a CCD video camera corresponds to 640x480 pixels with 8-bit depth, consuming just under 2.5 Mbits of memory. This large volume of data greatly reduces data transmission speed. Telemetry allows transmission of about 500 kbits/sec. Thus, it may be necessary to use data compression to transmit all the pixels for processing on the surface. The most efficient form of compression involves computing the final grain size downhole and then transmitting it uphole. See US Patent Application Serial No. 250,196 to Auzerais et al. filed 27 August 1994, for example, for a description of stereo and morphological algorithms. Data compression methods include two major schemes: lossless compression and lossy compression. On one hand, lossless compression reduces some amount of the data, but reconstructs the original data. Lossless compression is used in compressing ASCII text, for example. On the other hand, lossy compression provides an acceptable approximation of the original data with compression rates an order of magnitude greater than those of lossless compression. For still images, commercially available compression algorithms exist such as Px64, CIF, or, JPEG [ISO/IEC DIS 10918-1, Digital compression and coding of continuous-tone still image, January 1992.]. For moving images, commercially available compression algorithms also exist, such as MPEG [Quinnell, R. A., Image compression-Part 2, EDN, pp. 120. March 1993]. We have described the imaging of borehole walls on a microscale to reveal grain structure of a formation, for example. Borehole casings can also be imaged. We have described imaging of these borehole surfaces through not only clear formation fluids, but through opaque formation fluids also. Such imaging has wireline, logging-while drilling, coiled-tubing drilling, and production logging applications.

Claims: A downhole tool for obtaining formation properties comprising, a sampling means (54) having an inlet for providing fluid communication between the formation and the interior of the tool; a seal (28, 30) mounted adjacent the inlet to isolate an interval of the formation from borehole fluids located beyond the seal; a pump (16) for drawing fluid from the formation through the inlet of the sampling means (54); and characterized by means (100) for producing a signal comprising a two-dimensional representation of a portion of the isolated interval of the formation. The tool of claim 1, further including means (114) for reflecting wave energy from the portion of the isolated formation. The tool of claim 2, further including a detector (120) of InGaAs for receiving the wave energy which reflects from the isolated portion of the formation. The tool of claim 3, wherein the pump (16) for drawing fluid comprises a nozzle for placement adjacent the formation such that substantially formation fluid flows through the nozzle. The tool of claim 2, wherein the wave energy is characterized by visible light. The tool of claim 2, wherein the wave energy is characterized by near infrared light. The tool of claim 2, wherein the wave energy is characterized by ultrasonic energy. The tool of any one of claims 5 to 7, wherein the two-dimensional representation is an image (Figures 5a, 5b) which indicates rock texture of the portion of the isolated interval of the formation. A method for obtaining data concerning formation properties using a downhole tool comprising: providing fluid communication between the formation and the interior of the tool through an inlet to a sampling means (54) of the tool; isolating an interval of the formation from borehole fluids located beyond the interval with a seal (28, 30) mounted adjacent the inlet; drawing fluid, with a pump (16), from the formation through the inlet of the sampling means (54); and characterized by producing a signal representative of a two-dimensional representation of a portion of the isolated interval of the formation. The method of claim 9, further including reflecting wave energy from the portion of the interval to produce the signal. The method of claim 10, further including receiving the wave energy which reflects from the portion of the interval with a detector (120) of InGaAs. The method of claim 11, including drawing formation fluid with a nozzle (46, 48) placed adjacent the formation such that substantially formation fluid flows through the nozzle. The method of claim 10, further including reflecting wave energy which is characterized by visible light. The method of claim 10, further including reflecting wave energy which is characterized by near infrared light. The method of claim 10, further including reflecting wave energy which is characterized by ultrasonic energy. The method of any one of claims 13 to 15, wherein the two-dimensional signal is an image (Figures 5a, 5b) that indicates rock texture of the portion of the isolated interval of the formation.

Inventors: AUZERAIS FRANCOIS M, SCHROEDER ROBERT J, AUZERAIS, FRANCOIS M., SCHROEDER, ROBERT J., Auzerais, François M.
Applicants: SCHLUMBERGER LTD, SCHLUMBERGER SERVICES PETROL, SCHLUMBERGER TECHNOLOGY BV, SCHLUMBERGER LIMITED (A NETHERLAND ANTILLES CORP.), SCHLUMBERGER TECHNOLOGY B.V., SERVICES PETROLIERS SCHLUMBERGER
Application year: 1996
Main classification: E21B47
IPC codes: E21B49, G06T1, G01V8, E21B47, G01B11