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Completing an oil well or gas well involves a cementing procedure that connects and connects one or more well casings lining a wellbore to a surrounding subterranean formation.

<p dir="rtl">5 In the vast majority of cases, when well deepens increase, new casing strings are required and cemented in place. Several other factors also point to the need for many casing strings that are concentric or intertwined, such as compliant with safety and environmental policies. In general, the cement between these casing strings prevents the presence or movement of</p>

<p dir="rtl">10 Fluids within the delimited annular spaces between the nested casings and between the casing and the wellbore wall. In some wells, the cementing procedure extends from total depth to surface, while in other wells cement is present only between certain depths.</p>

It is of particular importance to determine the presence of fluid flow paths in the annular regions

<p dir="rtl">15th identified between casings and between the casing and the wellbore due to the absence of cement (or cement bond) at or between certain depths. The identification and characterization of these flow paths is particularly important in the case of dam and abandonment operations, particularly in deep water applications. .</p>

sonic tools or ultrasonic tools are used in

<p dir="rtl">20 industry standard for assessing cement binding to both formation and encapsulation and then inferring potential annular flow paths (i.e., leaks,</p>

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channels, gaps, and so on). In most of these cases, the assessment uses raw data from only one system of sensors to infer fluid flow variables via indirect methods. There is no current workflow that can integrate the many measurements obtained in Borehole model The current methods are also typically used

<p dir="rtl">5 To characterize the first casing-cement bond, precluding the evaluation of any subsequent interfaces if many casing strings extend into the well.</p>

US Patent No. 20140103202 relates to tools for evaluating composition and encapsulation and methods for evaluating composition, specifically a pulsed neutron tool and a synthesis acoustic tool for evaluation of composition via

<p dir="rtl">10 Encapsulation, safety evaluation of packing and cementitious reinforcement and methods for its use above.</p>

US Patent No. 5274604 relates to a method for determining hydraulic isolation for oilfield casings. More specifically, the interfaces between the different materials in the borehole are examined using ultrasonic energies. The resulting signals are vacuum filtered to reduce packaging sensitivity and increase surface sensitivity

<p dir="rtl">15th The last (deeper) interface represented, for example, by formation . reversals</p>

Click here to enter text..reflections

General description of the invention

One aspect of the invention relates to a method that includes:

Inserting a tool string into a wellbore borehole drilled during a formation, so that

<p dir="rtl">20 The wellbore aligns at least partially, first casing and second casing</p>

second casing overlaps concentrically with part of the first casing, so that a first annular space is defined between the first casing and the second casings and is filled with a first annular media, and a second annular space

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second annulus between second casings and wellbore wall and filled with second annular media;

Obtaining sonic data from the first and second loops using a sonic wave emitted from a sonic data instrument in the tool chain

<p dir="rtl">5 tool string;</p>

Perform a first deconvolution on the audio data to obtain the amplitude, frequency and phase of the sound wave according to its change by the first and second annular media;

Obtaining ultrasonic data from the first annular media using an ultrasonic wave from an ultrasonic data instrument

<p dir="rtl">10 ultrasonic data is in the tool string;</p>

Performing a second process of deconvolution on the ultrasonic data to obtain the amplitude, frequency and phase of the ultrasound according to its change by the first annular media;

Obtaining density data for the first annular medium using outgoing gamma rays

<p dir="rtl">15th With the density tool in the tool string;</p>

Perform a third deconvolution on the density data to obtain the far count values, the near count values, and the energy spectrum of the first annular medium;

Obtain neutron data for an encapsulated aperture using the neutron porosity tool in the tool string;

<p dir="rtl">20 Perform four deconvolution on neutron data</p>

for the encapsulated aperture to obtain the far count and near count values ​​for gamma rays generated by neutron scattering by one or more of the first two wrappings

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the second, the first and second ring modes, the formation, and to obtain the energy spectrum of the formation and the first and second ring modes;

Obtaining neutron porosity log data for an exposed hole from measurements applied to the wellbore encapsulation formation;

<p dir="rtl">5 A fifth deconvolution was performed on the neutron porosity recording data</p>

neutron porosity log data for the exposed aperture to obtain the far-count and near-count values ​​for gamma rays generated by neutron scattering in the formation, and to obtain the energy spectrum of the formation.

Another embodiment of the present invention relates to a well system that includes:

<p dir="rtl">10 A tool string movable into a wellbore drilled through a formation, such that the wellbore at least partially aligns the first casing and the second casing overlaps concentrically with part of the first casing, so that an annular space is defined between the first casing and the second casings, filling it with a first annular media, and defining a second annular space</p>

<p dir="rtl">15th second annulus between second casings and wellbore wall and filled with second annular media;</p>

A computer system comprising a processor and a computer-readable non-transitional medium, such that a computer system that is connected in a communicative manner to a tool string and a computer-readable medium that stores computer-readable program code, when applied by the processor, configures the processor to do the following:

<p dir="rtl">20 Operating an audio tool in the tool string to obtain sonic data from the first and second toroidal media using a sonic wave emitted by the audio data tool;</p>

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Perform a first deconvolution on the audio data to obtain the amplitude, frequency and phase of the sound wave according to its change by the first and second annular media;

Running an ultrasonic tool in the tool string Obtaining ultrasonic data from the first annular media using a wave

<p dir="rtl">5 ultrasonic wave from an ultrasonic data instrument;</p>

Performing a second process of deconvolution on the ultrasonic data to obtain the amplitude, frequency and phase of the ultrasound according to its change by the first annular media;

Run the density tool in the tool string Get

<p dir="rtl">10 Density data for the first annular medium using gamma rays from the density instrument;</p>

Perform a third deconvolution on the density data to obtain the far count values, the near count values, and the energy spectrum of the first annular medium;

Run a neutron porosity tool in the tool string to obtain 15 neutron data for an encapsulated aperture;

Perform a four-deconvolution process on the neutron data of the encapsulated aperture to obtain the far- and near-count values ​​of gamma rays generated by neutron scattering by one or more of the first and second sheathing, the first and second ring modes, and the formation, and to obtain Configurable Energy Spectrum

<p dir="rtl">20 the first and second annular medians;</p>

Obtaining neutron porosity log data for an exposed hole from measurements applied to the wellbore encapsulation formation;

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A fifth deconvolution is performed on the neutron porosity log data of the open hole to obtain the far-count and near-count values ​​of gamma rays generated by neutron scattering in the formation, and to obtain the energy spectrum of the formation.

<p dir="rtl">5 Brief explanation of the drawings</p>

The following figures are included to illustrate certain aspects of the present disclosure and are not to be viewed as being exclusive embodiments. Many modifications, changes, combinations and equivalents in form and function can be introduced to the technical subject that has been revealed, without departing from the scope of this disclosure.

Figure 1 is a well system that can use the principles of the current detection.

<p dir="rtl">10 Figure 2 depicts an enlarged cross-sectional projection of a portion of the wellbore presented in Figure 1.</p>

Figure 3 depicts an illustrative workflow method used to characterize the first cement interface presented in Figure 2.

Figures 4a-4c are comparison plots showing intensity values ​​derived from audio data.

<p dir="rtl">15th Figure 5 depicts an illustrative workflow method used to characterize the second, third and fourth cement interfaces of Figure 2.</p>

Figure 6 illustrates an illustrative processing system for initializing and/or controlling the tooling pipeline in Figure 1 and/or for executing the workflows in Figures 3 and 5.

Detailed description:

<p dir="rtl">20 The present disclosure relates to the field of borehole hydrocarbons hydrocarbons and, more specifically, methods for assessing the integrity of bonds that attach a wellbore casing to a wellbore and other casings.</p>

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The present disclosure describes improved methods and systems for cement evaluation and characterization in several casing strings that use sonic, ultrasonic, density, and neutrons to provide a more direct and accurate measurement of cement bond integrity by evaluating the interface density between cement and casing.

annular equivalent cement-casing interface density 5

Density due to the presence of water, oil, or gas. Previous attempts to assess cement bonding quality relied on indirect methods that use only data from acoustic and/or ultrasonic instruments to determine cement parameters such as compressive strength or cement bonding. The embodiments of the present disclosure, on the other hand, provide more direct and accurate measurements of the quality of cementitious bonds and characterization of

<p dir="rtl">10 Cement casing using acoustic, ultrasonic, and density instruments. The methods currently described improve the evaluation and characterization of cement within boreholes without the need to invest in new tools, new tooling components, or new tooling bodies.</p>

Figure 1 is a schematic diagram of a well system illustrating 100 that could use the principles of the present disclosure. As shown, a 102 wellbore is drilled from the site

contains subterranean formation 106 in a subterranean formation surface location 10415

On hydrocarbons it is retained. Inside the 102 wellbore there is at least one series of 108 casing tubes attached to the inner surface of the 102 wellbore. The 108 string of casing is fixed inside the wellbore 102 by flowing cement 110 into the annular space formed between the outer diameter of the casing 108 and the inner diameter of the wellbore 102. The resulting cement ties do not stick.

Not only does it encapsulate 108 inside wellbore 102, it also serves to isolate adjacent zones 112 A and 112 B within formation 106 from each other. The isolation of adjacent regions 112a,b can be important when one region 112a,b contains oil or gas and the other region includes a non-hydrocarbon fluid, such as water. In the event that the cement 25 110 surrounding the packing 108 is defective and fails to provide insulation to adjacent areas 112a, b, it can

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Water or fluids other than hydrocarbons move within the hydrocarbon producing region, diluting or contaminating the hydrocarbons within the producing region. In addition, defective cement 110 can cause fluids from areas 112a,b to migrate to surface site 104 through the annular space surrounding the packaging 5 108.

To detect possible defective cementitious connections between casing 108 and the wellbore 102 wellbore and between overlapping lengths of casing 108, a 114 tool string can be introduced into the wellbore 102 on a 116 conveyance, such as a drilling cable or slip cable. However, other suitable transportation can include drill pipe, coil pipe, downhole dredge,

<p dir="rtl">10 production tubes, and the like. In some embodiments, Transport 116 may be connected to a 118 surface processing unit, for example, in a truck or other surface structures or drilling rigs. The conveyor 116 transports the 114 series tool tubes to the wellbore 102 wellbore via a 120 pulley system and through a wellhead 122 installation, such as a slider or similar. 114 series tool tubes can include one</p>

<p dir="rtl">15th or more advanced drilling cable performance logging tools for cement integrity analysis 110 connecting the casing 108 to the wellbore 102 wellbore. As shown, for example, a series of tool tubes can include 114 sonic data tool a, 124 ultrasonic data ultrasonic data tool b, bulk density tool 124 density tool c, and 124 neutron porosity tool d .</p>

<p dir="rtl">20 The 124a acoustic data instrument can be one of the most common cement bond log (CBL) instrument, radial cement bond log (RCBL), and open-hole monopolar acoustic instrument. open-hole mono-pole sonic tool The 124 ultrasonic data tool can be one among the ultrasonic pulse-echo scanner and flexural scanner</p>

<p dir="rtl">25 scanner. The 124 bulk density tool can be a porous density tool</p>

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open hole nuclear The 124d neutron pore device can be a cased-hole (CH) nuclear porous device that can be extended into a jacketed wellbore borehole.

Figure 2 depicts an enlarged cross-sectional projection of the wellbore portion of the 102 wellbore presented in Figure 1 lined with first 108 casinga and 108 second casingb.

<p dir="rtl">5 The first cement layer 110a mediates the first and second casings 108a,b or is placed within an annular space of the first annulus 202a defined between the outer diameter of the first casing 108a and the inner diameter of the second casing 108b. A second cement layer 110b mediates the second casings 108b and formation 106 or is placed inside a second annular space 202 second annulusb between the outer diameter of the second casing 108b and formation 106.</p>

<p dir="rtl">10 and the second 110a, b on connecting the first and second casing strings 108a, b to the surrounding configuration 106 and to each other.</p>

A first casing-cement interface 206 is provided at the outer diameter of the first casing 108a and the first cementitious layer 110a. A second interface is provided between the casing and the cement 206b at the inner diameter of the second casing 108b and the cementitious layer.

<p dir="rtl">15th First 110a. A third interface between the casing and cement 206c is provided at the outer diameter of the second casing 108b and the second cement layer 110b, and a four interface between the casing and cement 206d is provided at the inner diameter of the formation 106 and the second cement layer 110b. According to the present disclosure, drill cable performance logging tools or 114 series piping sensors (Figure 1) can be used to identify and evaluate interfaces between sheathing and cement 206a-d.</p>

<p dir="rtl">20 Figure 3 depicts an illustrative workflow method 300 to characterize the properties of the first interface between casing and cement 206a. As shown, the workflow method 300 operates by inputting acoustic, ultrasonic, and density data, which can be obtained by running the sonic instrument 124a, ultrasonic instrument 124b, and mass-density instrument 124c, respectively, to the instrument pipe series 114 presented in Figure 1.</p>

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At 302, the audio tool 124a obtains acoustic data from the media within the annular space (also referred to here as “annular media”), which can be distinguished, for example, as cement 110a, b (Fig. 2) in the annular spaces 202a,b (Fig. 2). In short, the 124a sonic device works by emitting a sonic

<p dir="rtl">5 wave (also referred to as a sonic wave or sound wave) in a wellbore 102 and formation 106. The sound wave interacts with the media within the toroidal spaces 202a,b and then changes the properties of the sound wave according to the physical properties of the toroidal media. For example, the amplitude (A), frequency (ω), and/or phase (φ) of a sound wave can be adjusted and at least part of the modulated sound wave is reversed.</p>

<p dir="rtl">10 on the audio instrument 124a, which leads to the audio data.</p>

Deconvolution can then be performed on the audio data, as at 304, to obtain the amplitude (A, frequency (ω), and/or phase (φ) of the modulated audio wave. The amplitude can then be provided) amplitude (A, frequency (ω, phase φ)) convolution unfolded into the S-inverted form, as at 306.

<p dir="rtl">15th An inverted S model calculates the density value (ρis) of the annular media, as at 308.</p>

As is well known, acoustic impedance is the product of the velocity of the sound wave and the density of the media. An inverted S model of 306 can be configured to predict the acoustic impedance of toroidal media and then calculate its ρis density based on the predicted acoustic impedance ratio. The density of the cement can be a known value. set

<p dir="rtl">20 Acoustic instrument 124a Density of ρis toroidal media based on the modulated sound wave. The inverted model S also compares the density of the toroids as obtained by the inverted model S with the density of the toroids as determined by the audio instrument 124a. If the difference in the two values ​​of the stated densities occur in preferential proximity to each other (based on a predetermined standard deviation, for example), the density computed by an inverted model S is considered to be the equivalent density measure</p>

<p dir="rtl">25 For media within the annular space 202a, b. If the difference in the two density values ​​does not fall on</p>

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Preferred approximations, however, an inverted S model can then be configured to predict new acoustic impedance values ​​for toroidal media and recalculate the density using the new predictions. The process is repeated iteratively until the two intensity values ​​are at preferred proximity to each other.

Ultrasound 124b operates in a similar manner to sonic 124a, except that the wave

<p dir="rtl">5 The sound (referred to here as an ultrasonic or ultrasonic wave) emitted by the ultrasound instrument 124b is at a higher frequency than the sound wave emitted by the sonic instrument 124a. Because of its higher frequency, the ultrasound wave has a relatively smaller examination depth compared to the sound wave For example, the ultrasound can often traverse the first interface between the casing and cement 206a (Fig. 2) before scattering or</p>

<p dir="rtl">10 "dies down". By contrast, because of its lower frequency, the sound wave can penetrate wellbore 102 and formation 106 to a much deeper distance.</p>

As with the sound wave, the ultrasound can also be modulated by the toroidal media and the ultrasound can be received by the ultrasound instrument 124b. For example, the amplitude (A), frequency (ω), and/or phase (φ) can be adjusted.

<p dir="rtl">15th Ultrasonic wave according to the physical properties of the media within the toroid 202a (Fig. 2), resulting in ultrasonic data, as at 312. The ultrasonic data obtained can refer to the density of the toroidal media.</p>

The ultrasonic data then goes through a deconvolution process, as at 314, resulting in amplitude (A), frequency (ω), and phase (φ).

<p dir="rtl">20 Unscrew modulated ultrasound. The inverted ultrasonic (inverted-US) model can operate on amplitude (A), frequency (ω), and phase (φ) untied, as at 316, and can provide a calculation of the density (ρiUS) of the toroidal media, as Case at 318. As with the inverted model S, the inverted US model calculates the ρiUS value based on the ratio of the acoustic impedances of the annular media</p>

<p dir="rtl">25 media . In view of the non-interference of ultrasonic waves after the interface</p>

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The first casing-cement interface 206a, the ρiUS density of the toroidal media as calculated by the ultrasonic instrument 124b can be the density of the material (or media) at the first interface between the casing-cement interface 206a. The obtained ρiUS can be improved by an inverted model and revised (for example, frequently),

<p dir="rtl">5 In a similar way to the above for the inverted S model.</p>

At 310, the ρis density of the toroidal media obtained at 308 can be compared with the density of the toroidal media ρiUS obtained at 318. If the two densities are not in preferably close proximity to each other (for example, based on a predefined standard deviation) , an inverted S form and/or an inverted US form can be updated, as at 309, and then reset

<p dir="rtl">10 Calculate the respective intensity values ​​based on the updated S-inverted model and/or the updated US inverted model. For example, the corresponding inverted models can predict a different value of the acoustic impedance of the toroidal media and recalculate the intensity based on the different values. The process can be repeated iteratively until the density values ​​lie within the preferred proximity to each other, and then obtain the value of the median density at the first interface between the casing and cement 206a as measured by the tool</p>

15th Vocal 124a, as at 320.

Referring briefly to Figs 4a-4c, three graphs depicting the comparison of illustrative density measurements are shown. Density measurements are depicted as a normal (or Gaussian) distribution. In Fig. 4a, the upper plot depicts density measurements (ρS) obtained from the audio instrument 124a, and the lower plot depicts density measurements

<p dir="rtl">20 ρ Measurements (ρUS) obtained from ultrasound instrument 124b</p>

The 402 ground lines are the acceptable range of standard deviation that can be observed between the two density metrics (ρS, ρUS). As shown, the vertex of the bell curve of the normal distribution of density measurements (ρUS) obtained with the 124b ultrasound instrument lies within the 402 ground lines Thus, the density measurements (ρUS) obtained from the ultrasound instrument are considered

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124b and the density measurement (ρS) obtained from the 124a acoustic instrument are within preferred close proximity to each other.

In Figure 4b, the upper plot depicts density (ρis) measurements obtained from an inverted model S (as at 306, Fig. 3), and the lower plot depicts density measurements

<p dir="rtl">5 (ρiUS) obtained from an inverted US model (as at 316, Fig. 3).</p>

The 402 vertical lines represent the acceptable range of standard deviation that can be observed between two density measures (ρiUS, ρiUS). As shown, the vertex of the bell curve of the normal distribution of density measurements (ρiUS) obtained from the inverted US model lies within the 402 vertical lines Thus, the density measurements (ρiUS) obtained from the inverted model can be considered US .

<p dir="rtl">10 Within the preferred approximation of density measurements (ρiS) obtained from an inverted S model.</p>

In contrast, the density measurements (ρiUS) obtained from the inverted US model and the density measurements (ρiS) obtained from the inverted model S may not be within the preferred proximity of each other. In Figure 4c, for example, the tops of The bell curve of the normal distribution of ρiUS within the 402 baselines. In this case, a recalculation of the density measurements may be required, as mentioned above.

Returning to Fig. 3, the density data is obtained using the 124c density tool in Fig. 1, as with 322. When turned on, the 124c density tool fires gamma rays into the 102 wellbore, which are scattered by the toroids and the formation 106. Based on the gamma rays of the 124g density instrument,

<p dir="rtl">20 Obtain density data that includes far numbers, near numbers, and the energy spectrum of scattered gamma rays. The density of the toroidal media in the toroidal space 202a can then be calculated based on the density data.</p>

The density data goes through a deconvolution process that, as at 324, leads to the far numbers, the near numbers, and the energy spectrum of the scattered gamma rays . as when

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326, the deconvolution results are provided for a density inverse model with the density value of the ring media at the first interface between casing and cement 206a obtained at 320. An inverted D model can be configured to predict the equivalent density (ρeq). for ring media using its input, as at 328.

<p dir="rtl">5 The equivalent density of the ring media includes the media density at the first interface between the casing and the cement 206a and the cement density 110.</p>

From the equivalent density ρeq of the ring media, the density (ρiDens) of the media at the first interface between the coating and cement 206a can be predicted, as at 330. For example, the density of the media ρiDens at the first interface between the coating and cement 206a can be predicted based on 10 values The known density of cement is 110. As at 334, the density value can be compared to that

obtained at 330 with the density of the media at the first interface between the casing and cement 206a obtained at 320. If the difference in the two density values ​​is not within a preferred proximity to each other (eg, based on a predetermined standard deviation), the Update inverted form S and/or inverted form US, as at 309. It can then be

<p dir="rtl">15th The updated model(s) recalculate the corresponding density values, and the process is repeated iteratively until the density values ​​derived from an inverted model S and an inverted model D are within preferred proximity to each other.</p>

Once the density values ​​fall within the preferred proximity of each other, the media density at the first interface between the casing and cement 206a is known or obtained. Additionally 20, based on the media density at the first interface between the casing and the cement 206a,

Width (δ) may be specified for any "gap" present at the first interface between the casing and the cement 206a, as at 332. Here, the term 'gap' can refer to any non-rigid interface between the outer diameter of the first casing 108a and the cement 110a The workflow method 300 can then end with a calculation of the media density at the first interface between the casing and cement 25 206a and the thickness of the ring media, at 336. As shown, some operations of the flow method constitute

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Work 300 301 sub-routine, which can be used in the illustrative workflow method 500 in Figure 5 that will be discussed below to distinguish the properties of the second, third and fourth interfaces between 206b-d cement and sheathing.

Figure 5 depicts an illustrative workflow method of 500 to distinguish characteristics

<p dir="rtl">5 The second, third and fourth interfaces between the casing and cement 206b-d shown in Figure 2. Workflow method 500 may include some operations of workflow method 300 given in Figure 3, and thus can be better understood when referring to them, where similar numbers indicate To similar components will not be described in detail again. The results of the respective deconvolutions performed at 304, 314, and 324 described above can be provided in the method</p>

<p dir="rtl">10 Workflow 300 given in Figure 3 to subroutine 301 (Figure 3) to obtain media density at the first interface between casing and cement 206a and media thickness, as at 336. The media density and thickness, as obtained at 336 with capacitance, can be provided, as obtained at 336 (A), frequency (ω), and/or phase (φ) obtained from the deconvolution process (304) into the inverted audio model (inverted S model), as at 502.</p>

<p dir="rtl">15th The inspection depth of the ultrasonic instrument 124b and density instrument 124c is relatively smaller than the inspection depth of the sonic instrument 124a. As mentioned above, the ultrasound from the 124b ultrasonic device mostly scans the first interface between the casing and the cement 206a before it scatters or “finishes” likewise, gamma rays from the 124g instrument can mostly pass to the second interface between the casing and cement 206b. However, the sound wave can be carried out from</p>

<p dir="rtl">20 Vocal instrument 124a to Genesis 106.</p>

The second inverted S model 502 can be configured to predict the equivalent density of the toroidal media at the second and third interfaces between the encapsulation and cement 206b,c, as at 504. For example, the equivalent density can be predicted based on the ratio of the acoustic impedances of the toroidal media encountered by the sound wave. Using the equivalent density, a second inverted S model can predict 502

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Also, with the equivalent hydrogen index (HI) for the media at the first and second interfaces between the casing and cement 206b,c, as at 504.

At 512, the open-hole (OH) neutron data is acquired and then goes through a deconvolution process, at 514, which results in the far numbers and the near numbers of neutrons dispersed by the 5 configuration 106, and the energy spectrum. It should be recognized that data is acquired neutron

Open bore data from measurements made on formation 106 prior to wellbore casing 102 wellbore. Based on the results of the deconvolution, the hydrogen index (hydrogen hole (HI) for configuration 106 at 516) is obtained.

The neutron data also passes through the cased-hole (CH), which was

<p dir="rtl">10 Obtained at 522, by deconvolution, at 524, which results in far and near numbers corresponding to scattered neutrons, and an energy spectrum corresponding to the toroids in the first and second ring spaces 202a, b. Based on the results of the deconvolution process, a stoichiometric hydrogen index is obtained for the system which includes first and second coatings 108a, b, first and second cementitious layers 110a, b, and composition 106, as at 526.</p>

<p dir="rtl">15th Both the equivalent density and the equivalent hydrogen index for the second and third interfaces between the casing and cement 206b,c obtained at 504, the hydrogen index of the composition 106 obtained at 516, and the system equivalent hydrogen index obtained at 526 are given for an inverted model Neutrons (inverted N model), as at 528. An inverted N model predicts the hydrogen index of the four interfaces between the encapsulation and the cement</p>

<p dir="rtl">20 206d based on the given inputs.</p>

From the hydrogen indicators obtained at 504 and 528, the widths of the second and third interfaces between the casing and cement 206b,c can be obtained, as is the case at 530. To ensure that the rates of the widths of the second and third interfaces between the casing and cement 206b,c were obtained If at 530 falls within the predetermined standard deviation, then averages are provided

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Width for the third inverted S model, which then predicts the material density at the second and third interfaces between the casing and cement 206b,c based on the width rates obtained, as at 532. At 534, the predicted density is compared to the density of the toroidal media that Obtained from the second inverted S model (at 502). If the difference in the two intensity values ​​5 does not fall within the predetermined standard deviation, then the feedback is done by error (as at 536).

to the second inverted S model, which recalculates the corresponding density and the workflow continues based on the recalculated value. The comparison can serve as a check to determine if the media density at the second and third interfaces between the casing and cement 206b,c as obtained based on hydrogen indicators falls to the preferred approximation of the density of the same media as measured by

<p dir="rtl">10 Inverted Model S II.</p>

Once the intensity values ​​fall to the preferred approximation (as at 536), the . method can be set

Workflow 500 The presence of a non-rigid interface (i.e., a gap) at each first interface between the casing and cement 206a, the second interface between the casing and cement 206b, the third interface between the casing and cement 206c, and the four interface between the casing and cement 206d, as well as 15 It is the case at 538. When determining the presence of the four interfaces between the casing and cement 206D, compare

Workflow method 500 whether the hydrogen index (HI) of the composition is 106

obtained at 516 and the hydrogen index of the system obtained at 526 lie in preferential proximity to each other (for example, based on a predetermined standard deviation). If they are not the same, it can be determined that the difference in the hydrogen indices is due to a plus

<p dir="rtl">20 in hydrogen content caused by fluid (gas, water, or other media) present at an additional interface, the four interface 206d (as long as all other interfaces 206a-c have been previously identified). This fluid-filled gap is As long as the wellbore variables (eg, wellbore size, number of casings, casing widths and cement) are known, the fluid density at the four interface can be determined</p>

<p dir="rtl">25 206D and the width of the four interfaces is 206D, which leads to the hydrogen index being increased through the process</p>

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frequent. The presence of a gap at any of the interfaces between the casing and the 206a-d cement could indicate poor cementitious ligatures.

Using the 500 workflow method, the operator may be able to identify the presence of any gaps and can take the necessary steps to prevent leakage from the gap(s) so that transmission is prevented

<p dir="rtl">5 fluids from areas 112a, b (Fig. 1) or any other non-preferred fluids down the well to surface location 104 (Fig. 1).</p>

Figure 6 shows an illustrated processing system 600 to initialize and/or control the 114 tool tubes series in Figure 1, to implement the 300 workflow in Figure 3, and/or to implement the 500 workflow in Figure 5. The system can include 600 processors610 memory

<p dir="rtl">10 620, 630 storage device, and 640 I/O. Each . can be connected</p>

Components 610, 620, 630, and 640, for example, using the 650 system bus. The 610 processor may be capable of processing instructions to be executed within the 600 system. In some embodiments, the 610 processor is a single-thread processor, a multi-thread processor, or another type of processor. The 610 processor could be capable of processing

<p dir="rtl">15th Instructions stored in memory 620 or on storage media 630. The memory 620 and storage media 630 can store information within a computer system 600.</p>

I/O device 640 can provide 600 system I/O operations. In some embodiments, I/O device 640 can include one or more network interface devices, for example, an Ethernet card, a serial communication device, For example, port

<p dir="rtl">20 RS-232, and/or a wireless interface device, eg 802.11 card, wireless modem</p>

From the third generation, or a wireless modem from the fourth generation. In some embodiments, the I/O device may include drive devices configured to receive input data and send output data to other I/O devices, for example, a keyboard, printer and 660 displays. In some embodiments, arithmetic devices may be used portable, portable means of communication, and other means.

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Subject to at least some embodiments, the methods and systems disclosed herein may be implemented in connection with the survey and analysis of a substance in a digital electronic circuit, computer program, firmware, or computer component, including the architectures disclosed in this specification and their structural equivalents, or In combinations of one or more of them. A computer program can include, for example, one

<p dir="rtl">5 One or more instruction modules, encoded on a computer-readable storage medium, to be executed by, or to control the operation of, a data processing device. Examples of computer-readable storage media include non-temporary media such as random access memory (RAM), read only memory (ROM), optical media (for example, CDs or DVDs), and hard disk drives. .</p>

<p dir="rtl">10 The term "data processing device" includes all types of devices, devices, and machines for processing data, which include, for example, a programmable processor, a computer, a system on a chip, or several, or combinations of the foregoing. The device may include a special-purpose logic circuit, for example, an FPGA (field programmable gate array).</p>

application Defined Integrated Circuit (ASIC or) programmable gate array

<p dir="rtl">15th In addition to a computer component, the device also includes code that creates an execution environment for the computer program of interest, for example, code that constitutes processor firmware, a protocol stack, a database management system, an operating system, a cross-platform operating environment A virtual machine, or a combination of one or more of them A machine and an execution environment can realize many different infrastructures for a computer model, such as web services, computational infrastructures</p>

<p dir="rtl">20 Distributed and Network Computational.</p>

A computer program (also known as a program, software, application program, text, or code) can be written in any form of a programming language, including compiled or interpreted languages, or declarative or procedural languages. A computer program can be the same, but not necessarily, with a file in a file system A program may be stored in a portion of a file that contains programs or other data (for example, one or more

<p dir="rtl">25 The texts stored in a markup language document), in a single file designated for the program of interest, or in</p>

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Many formatted files (for example, files that store one or more modules, subprograms, or pieces of code). A computer program can be executed on a single computer or on many computers in a location or distributed over Several sites are connected by a network.

<p dir="rtl">5 Some of the operations and logical flows described in this specification may be performed by one or more programmable processors to execute one or more computer programs for the purpose of executing the procedures by acting on data input and output. Logical operations and flows can also be performed by, and the device can be implemented in the form of, a special purpose logic circuit, for example, an FPGA (field programmable gate array), or</p>

<p dir="rtl">10 ASIC (Application specific integrated circuit .)</p>

Processors suitable for executing a computer program include, for example, all general and special-purpose small-scale data processors, and processors of any kind from a digital computer. Generally, the processor will receive instructions and data from ROM, RAM, or both. A computer includes a processor to perform actions according to the instructions, and one or more memory devices to store

<p dir="rtl">15th Help and data. The software may also include, or be effectively combined to receive data from or transform the data, or both, into one or more quantum storage methods for data storage, for example, magnetic, magneto-optical, or optical disks. However, your computer may not have these media. Suitable means for storing computer program instructions and data include all non-volatile memory images, memory media and devices, including, for example</p>

<p dir="rtl">20 For example, semiconductor memory devices (for example, EEPROM, Erasable Programmable Read-Only Memory (EPROM, flash memory devices, etc.), magnetic disks (for example, internal hard disks, etc.), removable disks, etc.), magnetic optical disks, and CD-ROM</p>

Write COMPACT DISK READ ONLY MEMORY (CD-ROM)

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DIGITAL VEDIO DISK (DVD-ROM .)

RANDOM ACCESS MEMORY

. The processor and memory can be completed by, or included in, a special purpose logic circuit.

To provide interaction with the user, operations can be performed on a computer with a display (eg

<p dir="rtl">5 a screen, or other type of display) to display information to the user and a keyboard and pointing device (for example, a mouse, trackball, tablet, touch-sensitive screen, or other type of pointing device) through which the user can provide other types of means can be used to provide interaction with the user as well; for example, the feedback provided to the user could be any form of sensory feedback, for example</p>

<p dir="rtl">10 eg, visual feedback, toxic feedback, or tactile feedback; User input can be received in any form, including voice, speech, or tactile input. In addition, a computer can interact with a user by sending documents to and receiving documents from a medium used by the user; For example, by sending web pages to a web browser on a user's device in response to requests received from a browser</p>

<p dir="rtl">15th web.</p>

A computer system can include a single computing medium, or many computers operating close to each other or far from each other, and typically interacting over a network. Examples of networks include a local area network (LAN) and a wide area network (WAN). For example,

<p dir="rtl">20 Internet), a network that includes a satellite link, and peer-to-peer networks (for example, dedicated peer-to-peer networks). The respective computer and its slave-server relationship to each other.</p>

Embodiments disclosed here include:

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(a) A method involving insertion of a tool string into a wellbore borehole drilled through a formation and lined at least partially by first casing and second casing concentrically overlapping with part of the first casing, wherein a first annulus is defined between The first and second casings are filled with annular media

<p dir="rtl">5 First media, a second annulus is defined between the second casings and the wellbore wall and filled with a second annulus, sonic data sonic data for the first and second annulus using a sound wave</p>

sonic data sonic data tool from sonic wave sonic wave

Included in the tool tube series, first deconvolution operation

<p dir="rtl">10 on acoustic data to obtain the amplitude, frequency, and phase of the sound wave as changed by the first and second toroidal media, obtaining ultrasonic data for the first toroidal media using an ultrasonic wave from an ultrasonic data instrument included in the instrument pipe series, Perform a second deconvolution on the ultrasonic data to obtain the amplitude, frequency, and phase of the ultrasonic wave.</p>

<p dir="rtl">15th Acoustic as altered by first toroids Obtaining density data for first toroids using gamma rays from a density tool included in the Tool Tubes Performing a third deconvolution on the density data to obtain the far numbers, the near numbers, and energy spectrum of the first rings, neutron data acquisition of the encapsulated hole using an embedded neutron porosity instrument</p>

<p dir="rtl">20 In the Tool Tubes series, perform four dewarping on the encapsulated-hole neutron data to obtain the far numbers and near numbers of gamma rays produced by neutron scattering due to one or more of the first and second wrappings, the first and second rings, and formation, and to obtain Formation energy spectrum and first and second ring media, obtaining open-hole neutron porosity log data from measurements performed on formation</p>

<p dir="rtl">25 Before wellbore encapsulation, a fifth deconvolution is performed on the open-hole neutron porosity log data to obtain the far numbers and the near numbers of gamma rays</p>

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rays due to the scattering of neutrons in the formation, and to obtain the formation-specific energy spectrum.

b- A well system that includes a series of tool tubes that can be transported in a wellbore drilled through a formation and at least partially lined with first casing and second casing

<p dir="rtl">5 casing is concentrically overlapping with at least part of the first casing, where a first annulus is defined between the first and second casings and is filled with first annulus media, and a second annulus is defined between the second casings and a wellbore and is filled with a second annulus , a computer system that includes a processor and a non-temporary medium that is readable by the computer, and the computer system is connected connected to a series of tool tubes</p>

<p dir="rtl">10 The computer-readable medium stores the code of a computer-readable program that, when executed by the processor, configures the processor to operate an audio instrument included in the instrument pipeline to obtain sonic data for the first and second loop media using a sonic wave emitted by the audio data instrument, Perform a first deconvolution on the audio data to obtain the amplitude, frequency, and phase of the sound wave as changed by the first toroidal media.</p>

<p dir="rtl">15th Second, operation of an ultrasonic instrument included in the instrument-tube series to obtain ultrasonic data for the first toroidal media using an ultrasonic wave emanating from an ultrasonic data instrument, performing a second deconvolution on the ultrasonic data to obtain The amplitude, frequency, and phase of the ultrasound as changed by the first toroidal media, operation of the density tool</p>

<p dir="rtl">20 Included in Tool Tubes Series to obtain density data for first annulus using gamma rays emitted by a density instrument Perform a third deconvolution on the density data to obtain far numbers, near numbers, and energy spectrum for first toroids Operating a porous instrument The neutrons included in the instrument tube series to obtain neutron data encapsulated hole, performing the four deconvolution process</p>

<p dir="rtl">25 On the neutron data encapsulated hole to get the far numbers and the numbers</p>

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Nearby gamma rays generated by scattering neutrons due to one or more first and second wrappings, first and second rings, and formation, and to obtain formation energy spectrum and first and second rings, obtain open-hole neutron porosity log data from measurements made at Configuration before wellbore wellbore casing, the procedure

<p dir="rtl">5 A fifth deconvolution takes the open-hole neutron porosity log data to obtain the far numbers and near numbers of gamma rays caused by scattering neutrons in the formation, and to obtain the formation's energy spectrum.</p>

Each embodiment (a) and (b) may include one or more of the following additional elements in any combination: Element 1: which also includes a first inverted modeling procedure on

<p dir="rtl">10 Amplitude, frequency, and phase obtained via the first deconvolution to obtain a first density value for the first toroidal media based on the acoustic impedance characteristic of the first toroidal media, perform a second reciprocal modeling process on the amplitude, frequency, and phase obtained by Second deconvolution to obtain a second density value for the first toroidal media based on the acoustic impedance characteristic of the first toroidal media, and compare the value of</p>

<p dir="rtl">15th The first density and the second density value to determine if the first and second density values ​​lie in preferential proximity to each other. Element 2: It also includes obtaining a first interface density from the first density value when the first and second density values ​​lie in preferential proximity to each other, and the first interface density is the interface density value for the first sheathing and the first ring media. Element 3: which also includes at least one recalculation of the value of</p>

<p dir="rtl">20 The first density and the second density value when the first and second density values ​​do not fall to the preferred proximity of each other. Element 4: It also includes obtaining a third density value for the first toroids by performing a third reciprocal modeling process using the first interface density, the far numbers, the near numbers, and the energy spectrum of the first rings obtained through the third deconvolution process , obtaining a second interface density based on</p>

<p dir="rtl">25 The third density value, and the second interface density is the interface density value of the first laminator</p>

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and first toroidal media, comparing the density of the first interface with that of the second interface and obtaining the interface density of the first encapsulation and first toroidal media when the density rates of the first and second interfaces are within favorable proximity to each other. Element 5: It also includes recalculation of at least one of the first and second intensity values ​​when values ​​of . do not fall

<p dir="rtl">5 The densities of the first and second interfaces are on the preferred proximity to each other. Element 6: It also includes obtaining the first width of the interface at first casing and the first ring media when the density values ​​of the first and second interfaces are within preferred proximity to each other. Element 7: It also includes conducting a four-inverted modeling process using the density of the first ring media and the first presentation to calculate the density of a second interface and the density of a third interface 10, and the density of the second interface is the value of the interface density of the interface of the second coating and the first ring, and the density of the third interface is the value of Interfacial density of the second sheath and the second ring, Calculation of the hydrogen index of both the first ring and the second ring, Calculation of the open-hole hydrogen index of the formation using log data Open bore neutron porosity, wellbore . jacketed bore hydrogen indicator</p>

<p dir="rtl">15th Using the encapsulated hole neutron data, a second width of the interface of the second sheathing and the first cyclic media was calculated and a third width of the interface of the second sheathing and the second cyclic media was calculated by a fifth inverted modeling process performed on the density rates of the second and third interfaces, hydrogen index of the rings, hydrogen index For an open hole, the hydrogen indicator for a closed hole, a sixth inverted modeling process was performed using second width rates.</p>

<p dir="rtl">20 The third is to calculate the second interface density and the third interface density, and compare the second interface density and the third interface density computed through the four inverted modeling process with the second interface density and the third interface density computed through the sixth inverted modeling process. Element 8: It also includes obtaining the first, second, third and four interface density rates when the second interface density calculated through a process falls</p>

<p dir="rtl">25 The four inverted modeling is a preferable closeness to the second interface density computed through the sixth inverted modeling process, and the third interface density computed through the inverted modeling process lies</p>

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The four is a preferred distance from the third interface density computed through the sixth inverted modeling process, and the four interface density is the interface density value of the formation and the second toroidal media. Element 9: It also includes at least one recalculation of the second interface density and the third interface density computed through the four reciprocal modeling process when no

<p dir="rtl">5 The second interface density computed through the four inverted modeling process is a preferable closeness to the second interface density computed through the sixth inverted modeling process, or when the third interface density computed through the four inverted modeling process is not a preferable close to the third interface density Calculated via the sixth inverted modeling process.</p>

Element 10: The processor is also configured to perform a first reciprocal modeling process on the amplitude, frequency,

<p dir="rtl">10 and phase obtained via the first deconvolution process to obtain a first density value for the first toroidal media based on the acoustic impedance characteristic of the first toroidal media, perform a second reciprocal modeling process on the amplitude, frequency, and phase obtained by the second deconvolution To obtain a second density value of the first toroidal media based on the acoustic impedance characteristic of the first toroidal media, and compare the value of the first density</p>

<p dir="rtl">15th and the second density value to determine if the first and second density values ​​lie in preferential proximity to each other. Element 11: The processor is also configured to obtain a first interface density of the first density value when the first and second density values ​​lie in preferential proximity to each other, and the first interface density is the interface density value of the first encapsulation and the first ring media. Element 12: The processor is also configured to recalculate at least one of</p>

<p dir="rtl">20 The first density value and the second density value when the first and second density values ​​do not fall to the preferred proximity of each other. Element 13: The processor is also configured to obtain a third density value for the first toroids by performing a third reciprocal modeling process using the first interface density, far numbers, near numbers, and the energy spectrum of the first rings obtained through the deconvolution process Third, obtain the surface density</p>

<p dir="rtl">25 A second interface is based on the third density value, and the second interface density is the surface density value</p>

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The interface of the first coating and the first ring media, comparing the density of the first interface to that of the second interface and obtaining the density of the interface of the first coating and the first ring media when the density rates of the first and second interfaces are within favorable close proximity to each other.

Element 14: The processor is also configured to recalculate at least one of the first density values

<p dir="rtl">5 The second is when the first and second interface density values ​​do not fall to the preferred proximity to each other. Element 15: The processor is also configured to compute a first interface width at first casing and first toroidal media when the first and second interface densities are within preferred proximity to each other. Element 16: The processor is also configured to perform a four-reciprocal modeling process using the density of the first toroidal media and the first display to calculate</p>

<p dir="rtl">10 Second interface density and third interface density The second interface density is the interface density value for the second encapsulation and the first toroids The third interface density is the interface density value for the second encapsulation and the second toroids Calculate the hydrogen index for each of the first toroids And the second annular media, calculation of the open hole hydrogen index of the formation using the data of the open hole neutron porosity record, and the hole hydrogen index</p>

<p dir="rtl">15th Wellbore encapsulated using encapsulated bore neutron data, calculating a second width of the second casing interface and first cyclic media and a third width of the second casing interface and second annular media via a fifth inverted modeling process performed on the density rates of the second and third interfaces, hydrogen index of the media Toroidal, open hole hydrogen indicator, encapsulated hole hydrogen indicator, sixth inverted modeling procedure</p>

<p dir="rtl">20 Using the second and third width rates to calculate the second interface density and the third interface density, and compare the second interface density and the third interface density computed through the four inverted modeling process with the second interface density and the third interface density computed through the sixth inverted modeling process. Element 17: The processor is also configured to obtain the first, second, third and four interface densities when the density falls</p>

<p dir="rtl">25 The second interface computed through the four inverted modeling process is a preferable closeness to the second interface density computed through the sixth inverted modeling process, and the interface density lies</p>

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The third computed through the four inverted modeling process is at a preferred distance from the third interface density computed through the sixth inverted modeling process, and the four interface density is the interface density value of the formation and the second ring media. Element 18: The processor is also configured to recalculate at least one of the second interface densities and the third interface densities

<p dir="rtl">5 computed via the four-inverse modeling process when the second interface density computed through the four-inverted modeling process does not fall preferably close to the second interface density computed through the sixth inverted modeling process, or when the third interface density computed through the inverted modeling process does not Four is a preferred close to the third interface density computed via the sixth inverted modeling process.</p>

<p dir="rtl">10 As an unconstrained example, explanatory combinations applicable to a and b include: element 1 with element 2; element 1 with element 3; element 2 with element 4; element 4 with element 5; element 4 with element 6; element 6 with element 7; element 7 with element 8; element 7 with element 9; element 10 with element 11; element 10 with element 12; element 11 with element 13; element 13 with element 14; element 13 with element 15; element 15 with</p>

<p dir="rtl">15th element 16; element 16 with element 17; and element 16 with element 18.</p>

Thus, the revealed systems and methods are well adapted to obtain the stated ends and advantages as well as those inherent to them. The embodiments disclosed above are illustrative only, as the information in the present disclosure can be modified and implemented in various but equally skilled ways once the information herein has been made use of. Furthermore it,

<p dir="rtl">20 There are no restrictions on construction or design details herein, other than as described in the safeguards below. Consequently, it will be evident that the specific illustrative embodiments disclosed above can be changed, combined, or modified, and all such variations fall within the scope of the present disclosure. The systems and methods illustratively disclosed herein may be adequately implemented in the absence of any element not specifically disclosed herein and/or any element</p>

<p dir="rtl">25 Optional disclosed here. Whereas, compositions and methods are described in terms of “containing,” “containing.”</p>

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on", or "consists" of many components or steps, formulations and methods may also "mainly consist of" or "consist of" many components and steps. All numbers and ranges disclosed above may be of some quantity. Wherever a minimum and maximum numeric range is disclosed, any number and any contained range that falls within the range shall be specifically disclosed.

<p dir="rtl">5 In particular, it must be recognized that each range of values ​​(as “about A to about B,” or equivalently, “about A to B,” or equivalently, “from about A to B”) that is Disclosure here shows which number and range is included in the broader range of values ​​Also, terms in the claims have their ordinary, explicit meaning unless the contrary is expressly and explicitly specified by the patentee In addition, indefinite devices are defined, as used in Protection items, here</p>

<p dir="rtl">10 by being means one or more of the elements to which it refers. In the event of any inconsistency in the uses of a word or term in this specification and one or more patents or other documents that may be included here for reference, the definitions that align with this specification shall be used.</p>

As used herein, the phrase “at least one of” preceding a series of elements, modifies with the terms “and” or “or” to separate any of the elements, the list as a whole, rather than each member of the list (i.e.

<p dir="rtl">15th each element). The statement allows “at least one of” to mean at least one of any of the elements, at least one of any combination of elements, and/or at least one of each of the elements. each of the statements “at least one of a, b and c” or “at least one of a, b, or c” to a only, b only, or c only; and any combination of a, b and c; and and/or at least one each of a, b and c.</p>

<p dir="rtl">20 Graphics reference</p>

3 . shape

302 My voice

312 Ultrasound

322 density

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328 Toroidal Equivalent Density

306 Inverted Model-S

316 Inverted Model - US

326 Inverted-Density Model

<p dir="rtl">5 324 Energy Spectrum of Far and Near Detector Numbers</p>

a yes

b no

310 zero?

334 zero?

<p dir="rtl">10 336 Density and width of the interface between packing and cement</p>

308 Interface density between packing and cement

318 Interface density between packing and cement

330 Interface density between packing and cement

332 Interface width between packaging and cement

<p dir="rtl">15th Figure 4a, 4b, 4c</p>

A Gaussian or "normal" distribution

5 . shape

302 My voice

312 Ultrasound

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322 density

324 Energy spectrum of far and near detector numbers

514 Energy spectrum of far and near detector numbers

524 Energy spectrum of far and near detector numbers

<p dir="rtl">5 512 OH . neutron</p>

522 CH . neutron

534 zero?

a yes

b no

<p dir="rtl">10 502 Inverted Model-S</p>

301 The workflow method presented in Figure 3

336 Density and width of the interface between packing and cement

504 Density and HI rates of the second and third interface between the casing and the cement

530 Width rates for the second and third interface between packaging and cement

<p dir="rtl">15th 516 composition hydrogen indicator, HI</p>

526 Equivalent system hydrogen indicator, HI

528 Inverted Model-N

532 Inverted-S' Model

538 Density and width ratios of the interfaces between packing and cement

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6 . shape

<tr><td><p dir="rtl">Input/output devices</p></td><td><p>660</p></td></tr><tr><td><p dir="rtl">memory</p></td><td><p dir="rtl">a</p></td></tr><tr><td><p dir="rtl">in/out</p></td><td><p dir="rtl">B</p></td></tr><tr><td><p dir="rtl">storage medium</p></td><td><p>630 5</p></td></tr><tr><td><p dir="rtl">Processor</p></td><td><p>610</p></td></tr>

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