WO2015157270A1 - Casing string monitoring using electro-magnetic (em) corrosion detection tool and junction effects correction - Google Patents
Casing string monitoring using electro-magnetic (em) corrosion detection tool and junction effects correction Download PDFInfo
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- WO2015157270A1 WO2015157270A1 PCT/US2015/024690 US2015024690W WO2015157270A1 WO 2015157270 A1 WO2015157270 A1 WO 2015157270A1 US 2015024690 W US2015024690 W US 2015024690W WO 2015157270 A1 WO2015157270 A1 WO 2015157270A1
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- 230000000694 effects Effects 0.000 title claims abstract description 65
- 230000007797 corrosion Effects 0.000 title claims abstract description 27
- 238000005260 corrosion Methods 0.000 title claims abstract description 27
- 238000012544 monitoring process Methods 0.000 title claims abstract description 13
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Classifications
-
- 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
- G01V3/28—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 using induction coils
-
- 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
- E21B47/006—Detection of corrosion or deposition of substances
-
- 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
- E21B47/007—Measuring stresses in a pipe string or casing
-
- 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
- E21B47/09—Locating or determining the position of objects in boreholes or wells, e.g. the position of an extending arm; Identifying the free or blocked portions of pipes
- E21B47/092—Locating or determining the position of objects in boreholes or wells, e.g. the position of an extending arm; Identifying the free or blocked portions of pipes by detecting magnetic anomalies
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N17/00—Investigating resistance of materials to the weather, to corrosion, or to light
- G01N17/04—Corrosion probes
Definitions
- a network of wells installations and other conduits are established by connecting sections of metal pipe together.
- a well installation may be completed, in part, by lowering multiple sections of metal pipe (i.e., casing strings) into a borehole, and cementing the casing string in place.
- multiple casing strings are employed (e.g., a concentric string arrangement) to allow for different operations related to well completion, production, or enhanced oil recovery (EOR) options.
- Corrosion of metal pipes is an ongoing issue. Efforts to mitigate corrosion include use of corrosion-resistant alloys, coatings, treatments, corrosion transfer, etc. Also, efforts to improve corrosion monitoring are ongoing.
- various types of corrosion monitoring tools are available.
- One type of corrosion detection tool uses electromagnetic (EM) fields to estimate pipe thickness or other corrosion indicators.
- EM electromagnetic
- an EM logging tool may collect EM log data, where the EM log data can be interpreted to correlate a level of flux leakage or EM induction with corrosion.
- FIGS. 1A and IB depict various illustrative casing string survey environments.
- FIGS. 2 A and 2B show illustrative transmitter/receiver configurations for an EM logging tool.
- FIG. 3A-3F show illustrative casing string models and/or geometries.
- FIG. 4 shows a chart illustrating receiver signal versus logging position.
- FIGS. 5A-5B show illustrative flowcharts of multi-stage inversion methods that correct for junction effects.
- FIGS. 6 A and 6B show illustrative flowcharts of processing methods that correct for junction effects.
- Certain disclosed device, system, and method embodiments are directed to casing string corrosion monitoring using an electromagnetic (EM) logging tool and junction effects processing.
- EM log data is obtained along a casing string.
- the method also includes processing the EM log data to estimate casing thickness of the casing string as a function of position, where the processing operations corrects for junction effects in the casing string.
- the junction effects are corrected for using a multidimensional model (e.g., a 2D model).
- the junction effects are corrected for by comparing results of a one-dimensional (ID) casing string model with results of a multidimensional casing string model to identify junction effects, and re-processing the EM log data using the ID casing string model with junction effects removed.
- ID one-dimensional
- multi-stage inversion schemes that correct for junction effects may be employed.
- multistage inversion may include a first stage that inverts a junction location while a casing thickness is fixed, and a second stage that inverts a casing thickness while junction location is fixed using values determined in the first stage.
- the multi-stage inversion may also include a third stage that inverts a junction location and a casing thickness using values determined in the first and second stages as initial values.
- multiple iterations of a multi-stage inversion may be performed, where initial values for attributes to be determined for each stage are based on a previous iteration.
- the processing operations may apply a layer-sliding inversion and/or a constraint condition that limits an amount of variance between casing thickness results of a ID casing string model and casing thickness results of a multi-dimensional casing string model.
- the processing of EM log data may be performed downhole and/or at earth's surface to derive attributes (e.g., casing thickness, casing conductivity, and/or casing permeability) for a casing string as a function of depth.
- the derived attributes can further be correlated with one or more types of corrosion and/or with a corrosion index. If corrosion of a particular casing string is determined to exceed a threshold, a corrective action may be performed.
- Example corrective actions include enhancing, repairing, or replacing at least part of a casing segment. Additionally or alternatively, a treatment can be applied to reduce the rate of corrosion for at least part of a casing segment.
- FIGS. 1A and IB show illustrative casing string survey environments.
- FIG. 1A shows a permanent well survey environment, where a drilling rig has been used to drill borehole 16 that penetrates formations 19 of the earth 18 in a typical manner.
- a casing string 72 is positioned in the borehole 16.
- the casing string 72 of well 70 includes multiple tubular casing segments (usually about 30 feet long) connected end-to-end by couplings 76.
- FIG. 1C is not to scale, and that casing string 72 typically includes many such couplings 76.
- the well 70 includes cement slurry 80 that has been injected into the annular space between the outer surface of the casing string 72 and the inner surface of the borehole 16 and allowed to set.
- a production tubing string 84 has been positioned in an inner bore of the casing string 72. Both the casing string 72 and the production tubing string 84 are formed from multiple segments of metal pipe and are subject to corrosion.
- the well 70 corresponds to a production well and is adapted to guide a desired fluid (e.g., oil or gas) from a bottom of the borehole 16 to a surface of the earth 18. Accordingly, perforations 82 may be formed at a bottom of the borehole 16 to facilitate the flow of a fluid 85 from a surrounding formation into the borehole 16 and thence to earth's surface via an opening 86 at the bottom of the production tubing string 84.
- a desired fluid e.g., oil or gas
- perforations 82 may be formed at a bottom of the borehole 16 to facilitate the flow of a fluid 85 from a surrounding formation into the borehole 16 and thence to earth's surface via an opening 86 at the bottom of the production tubing string 84.
- well configuration of FIG. 1A is illustrative and not limiting on the scope of the disclosure. Other examples of permanent well installations include injection wells and monitoring wells.
- well 70 may include other casing strings in addition to or instead of casing string 72 and production tubing
- uplink or downlink information is transferred between an EM logging tool (see e.g., FIG. IB) and a surface interface 14 and/or computer system 20.
- the surface interface 14 and/or the computer system 20 may perform various operations such as converting signals from one format to another, storing EM log data collected by an EM logging tool, and/or processing EM log data to determine casing string attributes, where junction effects are corrected for.
- the computer system 20 includes a processing unit 22 that performs the EM log data analysis operations by executing software or instructions obtained from a local or remote non-transitory computer-readable medium 28.
- the computer system 20 also may include input device(s) 26 (e.g., a keyboard, mouse, touchpad, etc.) and output device(s) 24 (e.g., a monitor, printer, etc.).
- input device(s) 26 e.g., a keyboard, mouse, touchpad, etc.
- output device(s) 24 e.g., a monitor, printer, etc.
- Such input device(s) 26 and/or output device(s) 24 provide a user interface that enables an operator to interact with an EM logging tool and/or software executed by the processing unit 22.
- the computer system 20 may enable an operator to select analysis options, view collected EM log data, view analysis results, and/or perform other tasks.
- FIG. IB illustrates a wireline logging environment in which an EM logging tool 40 is positioned within production tubing string 84 and casing string 72.
- the EM logging tool 40 is suspended in borehole 16 that penetrates formations 19 of the earth 18.
- the EM logging tool 40 may be suspended by a cable 15 having conductors and/or optical fibers for conveying power to the EM logging tool 40.
- the cable 15 may also be used as a communication interface for uphole and/or downhole communications.
- the cable 15 wraps and unwraps as needed around cable reel 54 when lowering or raising the EM logging tool 40.
- the cable reel 54 may be part of a movable logging facility or vehicle 50 having a cable guide 52.
- the EM logging tool 40 includes stabilizers 42 on opposite ends of main body 41 to centralize the tool 40 within the production tubing string 84.
- the main body 41 of the EM logging tool 40 includes control electronics 44, transmitter(s) 46, and receiver(s) 48.
- transmitter(s) 46 are directed by the control electronics 44 to generate a time-varying EM field whose flux is guided by the production tubing string 84 and/or casing string 72.
- the flux induces a voltage in receiver(s) 48.
- the flux guide provided by the production tubing string 84 and/or casing string 72 is lossy due to induced eddy currents.
- the control electronics 44 store the voltages recorded by receiver(s) 48 to form an EM data log, which may be correlated with geometrical, electrical, and/or magnetic attributes of the production tubing string 84 and/or casing string 72. Corrosion of the production tubing string 84 and/or casing string 72 affects their geometrical, electrical, and/or magnetic attributes and can therefore be estimated from analysis of the EM log data.
- the control electronics 44 may also include a communication interface to transmit the EM data log to earth's surface. Additionally or alternatively, the EM data log obtained by the EM logging tool 40 can be stored and accessed later once the tool 40 reaches earth's surface.
- the surface interface 14 receives the EM data log via the cable 15 and conveys the EM field measurements to a computer system 20.
- the interface 14 and/or computer system 20 may perform various operations such as converting signals from one format to another, storing the EM log data, and/or analysis the EM log data to determine casing string attributes, where junction effects are corrected for.
- FIGS. 2 A and 2B show illustrative transmitter/receiver configurations for an EM logging tool (e.g., tool 40).
- transmitter 46 and receiver 48 are positioned within a casing string (e.g., strings 72 or 84) and are separated.
- transmitter 46 and receiver 48 are positioned within a casing string (e.g., strings 72 or 84) and are collocated.
- transmitter 46 and receiver 48 may correspond to coils or solenoids, where the receiver 48 is positioned inside the transmitter 46, or vice versa. While only one transmitter 46 and one receiver 48 are shown in FIGS.
- EM logging tools such as tool 40 may have a plurality of sensor arrays, where the distance between transmitters 46 and receivers 48 for different sensor arrays may vary. Further, the operation of each sensor arrays may be varied by frequency-domain or time- domain adjustments.
- FIGS. 3A-3F shows illustrative casing string models and/or geometries.
- a sensor array 49 e.g., one or more transmitter/receiver arrays
- the sensing array 49 may be part of an EM logging tool such as tool 40 to enable various attributes of the casing string (e.g., representative of strings 72 or 84) to be estimated.
- casing thickness (h), conductivity ( ⁇ ), and permeability ( ⁇ ) are shown to be uniform along the axial direction. If casing materials are known, the attributes to be determined for the casing string of FIG. 3A include the outer diameter (OD), h, ⁇ , and ⁇ .
- FIG. 3 A represents a ID casing string model, due to the uniformity of h, ⁇ , and ⁇ regardless of axial or radial position.
- FIGS. 3B-3F represent two-dimensional (2D) casing string models. More specifically, the casing string model of FIG. 3B shows a casing string with a small defect 60 (smaller than the size of the sensor array 49), where the thickness of the casing string is not uniform. The thickness non-uniformity along the axial direction of the casing string of FIG. 3B creates junctions (sometimes referred to as "shoulders" where the casing geometry varies) between different sections of the casing string.
- junctions sometimes referred to as "shoulders" where the casing geometry varies
- casing section used herein is a generic term that refers to any portion of a casing string having multiple segments connected together. Accordingly, the variations in casing string attributes (e.g., Z and h) may or may not occur where casing segments (e.g., 30 ft segments) connect together. Further, the variations in casing string attributes may occur along the length of a single casing segment. Due to its small size relative to the sensor array 49, the defect 60 is difficult to detect as the EM log data is affected by sections of the casing string that are above and/or below the small defect 60. For the casing string model of FIG. 3C, the casing string has a large defect 62 (larger than the size of the sensor array 49).
- the casing string model of FIG. 3D shows a casing string with uniform thickness along the axial direction, but with non-uniform conductivity or permeability. More specifically, the upper section of the casing string in FIG. 3D has conductivity ( ⁇ ) and permeability ( ⁇ ), while the lower section of the casing string has a different conductivity ( ⁇ 2 ) and permeability ( ⁇ 2 ).
- FIG. 3E shows a synthetic casing string model with attribute values used to generate chart 100 of FIG. 4.
- the thickness of the casing string is 0.28 inches except in section 66, where the thickness is reduced to 0.20 inches. Further, the outer diameter of the casing string is 5 inches.
- the transmitter and receiver coils are concentric and are operated in time-domain fashion, where time-decay EM signals are received right after the transmitter is turned off.
- the radius of the transmitter is 0.4 inches
- the radius of the receiver is 0.35 inches
- the casing conductivity is 4,000,000 S/m
- FIG. 3F shows a two-dimensional casing string model, where the casing string has non-uniform thickness, permeability, and/or conductivity along the axial direction.
- a two-dimensional casing string model is defined by more parameters or attributes.
- a three-dimensional (3D) casing string model may be employed, where casing string attributes (Z, h, ⁇ , and ⁇ ) may vary as a function of axial position, longitidual position, and/or azimuthal position.
- casing thickness is assumed to uniform along the axial direction. If casing materials are known, the attributes to be determined for a casing string include outer diameter (ODi), thickness (hi), conductivity ( ⁇ ), and permeability ( ⁇ ). To calculate the casing thickness, a numerical optimization (e.g., a Gauss-Newton method) may be employed. In such case, unknown parameters are adjusted until the misfit error between measurement data and predicted data (computed via forward modeling using estimated parameters) are sufficiently small. This goal can be achieved by iteratively solving a non-linear problem that minimizes the objective cost function:
- Sj X is the modeled tool response corresponding to a particular value of attribute vector X.
- the EM logging tool 40 is operated as a time-domain tool, measured data rrij are usually selected time bins corresponding to different casing diameter. On the other hand, if the EM logging tool 40 is operated at a frequency or multiple frequencies, measured data rrij are collected signals at frequency or frequencies used. If multiple transmitter-receiver arrays are employed in the EM logging tool 40, measured data rrij are tool responses (frequency or time-domain) from all of the selected arrays.
- Equations 1 and 2 can be implemented straightforwardly by using classical optimization methods when the casing thickness and material is close to uniform. However, it becomes inaccurate in other scenarios such as when a small casing defect is present (see e.g., FIG. 3B), when a sensing array is near a junction between different sections (see e.g., FIG. 3C), or when casing conductivity or permeability varies (see e.g., FIG. 3D).
- an EM logging tool such as too 40 is close to a junction between casing sections with different geometrical, electrical, and/or magnetic properties, received signals are likely to be affected by both casing sections rather than by just a single casing potion. If a ID casing string model is used to process the EM log data in the above scenarios, the numerical optimization to determine casing attributes may not be sufficiently accurate.
- Equations 1 and 2 may be employed, where Sj (X) is the modeled tool response corresponding to a particular value of casing attribute vector X.
- Sj (X) is the modeled tool response corresponding to a particular value of casing attribute vector X.
- X [OD; Z3 ⁇ 4; ty; ⁇ 3 ⁇ 4; 3 ⁇ 4] (see FIG. 3F).
- refers to the L2-norm.
- measured data rrij are usually selected time bins.
- measured data m ; - are collected signals at the frequency or frequencies used.
- measured data rrij are tool responses (frequency or time-domain) from all of the selected arrays.
- ID casing string model as described herein is sometimes referred to as ID processing model
- 2D casing string model as described herein is sometimes referred to as a 2D processing model
- processing using a ID casing string model is sometimes referred to as ID processing
- processing using a 2D casing string model is sometimes referred to as 2D processing
- a multi-dimensional casing string model (e.g., 2D or 3D) may be referred to as a multi-dimensional processing model
- processing using a multi-dimensional casing string model may be referred to as multi-dimensional processing.
- Processing Scheme A a multi-stage processing scheme (referred to herein as Processing Scheme A) is proposed to produce an accurate estimation of casing thickness.
- ID processing is first conducted to provide approximate results.
- 2D processing is employed to produce more accurate results that correct for junction effects.
- the Processing Scheme A (operations A 1 to A 10) is performed as follows:
- the initial junction locations are determined by a variance based method of a calculated ID casing thickness forward model (hid).
- the variances of hid at all logging logs are computed within a predefined position window (related to the maximum resolution of the EM logging tool). All logging points with peak value of the variance curve larger than a predefined threshold value are selected as starting boundaries. These starting boundaries are then examined and filtered to ensure that only one bed boundary point can exist within a predefined position window (related to the maximum resolution of the EM logging tool).
- the boundaries can also be estimated from initial collected raw logging data. If raw logging data is noise, appropriate smoothing filter has to be applied first.
- A6 Create initial 2D processing model using ID processing results.
- the initial casing thickness and all other unknown parameters are assumed to be same as results from ID processing.
- the initial forward model (h2d) is equal to the hid computed at the middle point of each section.
- a layer-sliding inversion scheme can be applied.
- a layer-sling inversion a fixed number of layers are modeled in each sub inversion window. After the problem of a sub inversion window is solved, the first layer's formation parameters will be marked as known and removed from the next sub inversion window. Meanwhile, a new layer will be included in the next inversion window. More implementation details for layer- sliding inversions can be found in WO 2014011190 Al, entitled "Method of estimating anisotropic formation resistivity profile using a multi-component induction tool.”
- A8 Calculate casing thickness using the 2D processing model. a. Following the general 2D processing scheme (e.g., defined as Equations 1 and 2 with modified parameters), casing thickness, casing section boundaries along with casing material are iteratively updated until a 2D processing model is obtained which can reproduce measured values.
- the general 2D processing scheme e.g., defined as Equations 1 and 2 with modified parameters
- a multi-stage inversion includes multiple stages, where a different casing string attribute or set of attributes is inverted for each stage while other casing string attributes are fixed.
- X [Zj, ty].
- the ty values are fixed and only the Zj values are inverted.
- the Zj values may be estimated directed from the received EM data as explained for block 202 of method 200A below. After the Zj values are calculated, they will be used as fixed values for the next stage.
- the Zj values are fixed (using the values determined in the first stage) and only the ty values are inverted.
- both ty and Zj are inverted using the values determines in the first and second stages as the initial values.
- measured data at the logging position close to middle region of each section casing are preferred since they are more sensitive to casing thickness.
- measured data at the logging position close to junctions are preferred since the measured data will be more sensitive to junction effects.
- FIG. 5 A and 5B show illustrative flowcharts of multistage inversion methods 200A and 200B that correct for junction effects.
- the method 200A is related to the processing operation of A8(b) given above.
- the method 200B shows a similar approach where additional iterations are employed to perform a sweep update of the first and the second stages. More specifically, the method 200 A selects data points close to casing junctions (block 202). As an example, data points close to junctions can be identified by the variance in the received signal exceeding a threshold amount.
- values for Z are estimated. For example, in some embodiments, Z may be estimated from the received data as the locations where variance in the received signal is highest.
- Z may be estimated by performing an inversion, where only values for Z are inverted while values for h are fixed.
- data points close to a middle region for each casing section are selected. For example, data points close to a middle region for each casing section can be identified by the variance in the received signal being less than a threshold amount.
- only values for h are inverted while values for Z are fixed (e.g., using the values for Z determined in block 204).
- data points close to casing junctions and the middle region of each casing section are selected.
- values for both Z and h are inverted.
- the method 200B includes the same blocks 202, 204, 206, and 208 described for method 200A.
- the method 200B determines whether to perform additional iterations (decision block 214). If so, the method 200B repeats blocks 202, 204, 206, and 208, where values determined in a previous iteration are used as the initial values for the attributes to be determined (e.g., Z in block 204, and h in block 208). Once a threshold quality or threshold number of iterations are achieved, the method 200B ends. While, methods 200A and 200B obtain values for Z and h, it should be appreciated that values for ⁇ and/or ⁇ could additionally or alternatively be obtained in a multi-stage inversion. Further, it should be appreciated that the order of the stages may vary (e.g., ⁇ , ⁇ , and/or h may be determined before Z).
- Equation 2 For example, following term can be added to Equation 2:
- Cnew VO C(X) + ⁇ Xj ⁇ - ⁇ d ⁇ 2 , Equation (3) where C new (X) ensures the computed result h from the 2D processing model is within a threshold amount relative to hj d determined from the ID processing model, where p is the current iteration, j is the casing section number, and ctj is a value determined from numerical experiments.
- A9. Determine if all windows have been processed. If yes, go to the next operation.
- FIG. 6A shows an illustrative flowchart of a processing method 300A that corrects for junction effects.
- the method 300A is related to the Processing Scheme A discussed previously.
- EM log data is collected at block 302.
- values for h are calculated using a ID processing model. If all logging positions have not been analyzed (decision block 306), the method 300A proceeds to a new position at block 308. Thereafter, blocks 302 and 304 are repeated for the new position.
- an initial 2D processing model is created from the ID processing model (block 310).
- a first processing window is selected (e.g., a layer-sliding window scheme is employed).
- casing thickness is calculated using the 2D processing model. If all the processing windows have not been analyzed (decision block 316), the method 300A moves to the next processing window (block 318) and block 314 is repeated for the new processing window. Once all the processing windows have been analyzed (decision block 316), the method 300A ends.
- Processing Scheme B An alternative scheme referred to herein as Processing Scheme B can be derived from Processing Scheme A, which is computationally expensive due to the 2D processing model.
- the Processing Scheme B performs ID processing to provide approximate results.
- an estimated 2D processing model is analyzed to remove junction effects on the original raw data.
- the raw data is modified to correct for junction effects, and ID processing is performed again using the modified raw data.
- the Processing Scheme B is more accurate compared to using a ID processing model alone and is less computationally expensive than the Processing Scheme A.
- the Processing Scheme B (operations Bl to B15) is performed as follows:
- the initial junctions are determined by a variance based method of calculated ID casing thickness in a forward model (hid).
- the variances of hid at all logging logs are computed within a predefined position window (maximum vertical resolution of the tool). All logging points with peak value of the variance curve larger than a predefined threshold value are selected as starting junctions. These starting junctions are then examined and filtered to ensure that only one junction can exist within a predefined position window (related to the maximum resolution of the tool).
- junctions can also be estimated from initial collected raw logging data (see block
- B6 Create initial 2D processing model using ID processing results.
- a To provide the initial model for 2D processing, the initial casing thickness and all other unknown parameters are assumed to be same as results from ID processing.
- the initial forward response for the 2D processing model (h 2 d) is equal to the forward response for the ID processing model (hid) computed at the middle point of each section.
- a layer-sliding inversion scheme can be applied as described for Processing Scheme A.
- a fixed number of layers are modeled in each sub inversion window. After the problem of a sub inversion window is solved, the first layer's formation parameters will be marked as known and removed from the next sub inversion window. Meanwhile, a new layer will be included in the next inversion window.
- the processing starts from the first window.
- An estimated 2D processing model has been created from operation B6.
- the forward response (f 2 d) of such a 2D model with the current window is computed, where f 2 d is a function of (OD, Zj, ty, Oj , 3 ⁇ 4) defined in the current processing window.
- Equation 4 cannot totally remove junction effects because both ID and 2D processing models used to calculate forward response may not be accurate enough. To address this potential issue, additional iterations can be utilized to improve its accuracy, by further removing junction effects.
- FIG. 6B shows an illustrative flowchart of a processing method 300B that corrects for junction effects.
- the method 300B is related to the Processing Scheme B discussed previously.
- blocks 302, 304, 306, and 308 are the same as the method 300A of FIG. 6A.
- junction locations are detected from the ID processing results (block 320).
- an initial 2D model is created from the 2D processing results.
- a first processing window is selected (e.g., a layer-sliding window scheme is employed).
- a forward response (f 2 d) using the 2D model is calculated within the selected processing window.
- a response that corrects for junction effects is computed at the current logging position.
- the corrected response is used to calculate h in a ID model.
- the method 300B determines whether all logging positions have been analyzed (decision block 332). If not, the method 300B proceeds to a next logging position within the selected processing window (block 334), and repeats blocks 328 and 330. If all logging positions have been analyzed (decision block 332), the method 300B determines is all processing windows have been analyzed (decision block 336). If not, the method 300B proceed to a next processing window (block 338), and repeats blocks 326, 328, and 330. If all processing windows have been analyzed (decision block 336), the method 300B determines whether to perform additional iterations (decision block 340). If not, the method 300B ends. Otherwise, the method 300B returns to block 302 to perform another iteration. The method 300B may perform additional iterations until a quality threshold or iteration count is reached.
- a corrosion monitoring method that comprises obtaining EM log data along a casing string, and processing the EM log data to estimate casing thickness of the casing string as a function of position. The processing corrects for junction effects in the casing string.
- B A corrosion monitoring system that comprises an EM logging tool to collect EM log data along a casing string, and a processing unit in communication with the EM logging tool. The processing unit processes the EM log data to estimate casing thickness of the casing string as a function of position, wherein the processing unit corrects for junction effects in the casing string.
- each of the embodiments, A and B may have one or more of the following additional elements in any combination.
- Element 1 correcting for junction effects in the casing string comprises employing a multi-dimensional casing string model.
- Element 2 correcting for junction effects further comprises applying a multi-stage inversion with multiple stages, where a different casing string attribute or set of attributes is inverted for each stage while at least one other casing string attribute is fixed.
- Element 3 the multi-stage inversion comprises a first stage that inverts a junction location while a casing thickness is fixed, and a second stage that inverts a casing thickness while junction location is fixed using values determined in the first stage.
- the multi-stage invention further comprises selecting EM log data at or near a casing junction for the first stage, and selecting EM log data at or near a middle region of a casing section for the second stage.
- the multi-stage inversion further comprises a third stage that inverts a junction location and a casing thickness using values determined in the first and second stages as initial values.
- the multi-stage inversion further comprises performing multiple iterations of the multi-stage inversion, where initial values for attributes to be determined for each stage are based on a previous iteration.
- correcting for junction effects in the casing string comprises comparing results from a ID casing string model and a multi-dimensional casing string model to identify the junction effects, and re-processing the EM log data using the ID casing string model with the junction effects removed.
- correcting for junction effects in the casing string comprises estimating junction positions directly from the EM log data, and inverting at least one other casing string attribute while a junction position attribute based on said estimating is fixed.
- correcting for junction effects in the casing string comprises calculating a first forward response using the multi-dimensional model and a second forward response using the ID model, and wherein comparing results comprises comparing the first and second forward responses.
- Element 10 correcting for junction effects in the casing string comprises using a ID model to identify one or more casing string attributes, and setting values for a multi-dimensional model based on the one or more casing string attributes determined using the ID model.
- Element 11 correcting for junction effects in the casing string comprises applying a layer-sliding inversion.
- Element 12 correcting for junction effects in the casing string comprises applying a constraint condition that limits an amount of variance between casing thickness results of a ID casing string model and casing thickness results of a multidimensional casing string model.
- Element 13 the processing unit corrects for junction effects in the casing string by performing a multi-stage inversion with multiple stages, where a different casing string attribute or set of attributes is inverted for each stage while at least one other casing string attribute is fixed.
- the multi-stage inversion further comprises a stage that inverts a junction location and a casing thickness using values determined in previous stages as initial values.
- Element 15 the processing unit performs multiple iterations of the multi-stage inversion, where initial values for attributes to be determined for each stage are based on a previous iteration.
- Element 16 the processing unit accounts for junction effects in the casing string by comparing results from two different models to identify the junction effects, and Re-processing the EM log data using one of the different models with the junction effects removed.
- Element 17 the processing unit corrects for junction effects in the casing string based on a multi-dimensional casing string model.
- Element 18 the processing unit corrects for junction effects in the casing string by applying at least one of a layer-sliding inversion, and a constraint condition that limits an amount of variance between casing thickness results of a ID model and casing thickness results of a multi-dimensional model.
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Priority Applications (4)
Application Number | Priority Date | Filing Date | Title |
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MX2016011802A MX2016011802A (en) | 2014-04-10 | 2015-04-07 | Casing string monitoring using electro-magnetic (em) corrosion detection tool and junction effects correction. |
EP15777588.3A EP3129589A4 (en) | 2014-04-10 | 2015-04-07 | Casing string monitoring using electro-magnetic (em) corrosion detection tool and junction effects correction |
US15/118,998 US10234591B2 (en) | 2014-04-10 | 2015-04-07 | Casing string monitoring using electromagnetic (EM) corrosion detection tool and junction effects correction |
SA516371858A SA516371858B1 (en) | 2014-04-10 | 2016-09-18 | Casing String Monitoring using Electromagnetic (EM) Corrosion Detection tool and Junction Effects Correction |
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US201461978127P | 2014-04-10 | 2014-04-10 | |
US61/978,127 | 2014-04-10 |
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PCT/US2015/024690 WO2015157270A1 (en) | 2014-04-10 | 2015-04-07 | Casing string monitoring using electro-magnetic (em) corrosion detection tool and junction effects correction |
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US (1) | US10234591B2 (en) |
EP (1) | EP3129589A4 (en) |
MX (1) | MX2016011802A (en) |
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WO (1) | WO2015157270A1 (en) |
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US10234591B2 (en) | 2019-03-19 |
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US20170038493A1 (en) | 2017-02-09 |
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