CN113295569B - Shale oil-gas reservoir protection effect detection method and device - Google Patents
Shale oil-gas reservoir protection effect detection method and device Download PDFInfo
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Abstract
The disclosure provides a method and a device for detecting a shale oil-gas reservoir protection effect, and belongs to the technical field of oil-gas reservoir protection. The detection method comprises the following steps: manufacturing a first rock sample based on a shale oil and gas reservoir to be tested, and drying the first rock sample to constant weight; manufacturing a second rock sample based on the shale oil gas reservoir to be tested, wherein the second rock sample has the same appearance as the first rock sample, the difference value between the permeability is smaller than a preset threshold value, and then soaking the second rock sample by using the aqueous solution of the treating agent to be tested, and drying the second rock sample to constant weight; acquiring a first imbibition amount and a second imbibition amount, wherein the first imbibition amount is the imbibition amount of a first rock sample to drilling fluid filtrate, and the second imbibition amount is the imbibition amount of a second rock sample to drilling fluid filtrate; and detecting according to the first imbibition amount and the second imbibition amount to obtain the protection effect of the aqueous solution of the treating agent to be detected on the shale oil-gas reservoir to be detected. The surface modification degree of the treating agent to the shale oil and gas reservoir is reflected by testing the imbibition difference of the second rock sample and the first rock sample to the drilling fluid filtrate.
Description
Technical Field
The disclosure belongs to the technical field of oil and gas reservoir protection, and particularly relates to a method and a device for detecting a shale oil and gas reservoir protection effect.
Background
The hydrocarbon reservoir needs to be protected during the exploration and development of the oil and gas field. The protection method is generally a rock surface modification method, and the wettability of the pore surface of the core in the shale reservoir is changed by the rock surface modification method, so that the protection effect is achieved.
In the related art, when the rock surface modification method is performed, a specially treated treating agent (also called a wetting reversal agent) is added into the drilling fluid, so that the treating agent enters the shale reservoir together with the drilling fluid during drilling so as to protect the hydrocarbon reservoir. The protection effect is related to the productivity of the oil and gas well, and the protection effect of the oil and gas layer needs to be detected in order to ensure the productivity of the oil and gas well. In the related art, the protection effect of the hydrocarbon reservoir is evaluated by detecting the modification performance of the treating agent on the shale reservoir, and the method of detecting the self-imbibition height, the contact angle change, the surface liquid drop state and the like of the capillary is generally adopted.
However, the method for detecting the modification performance of the treating agent on the shale reservoir is a preliminary study on the surface performance of the treating agent before the actual use of the treating agent, so that only qualitative study can be carried out, the effect of the treating agent on the shale reservoir cannot be directly evaluated, namely, the effect result on the rock core cannot be obtained, and the detection result is inaccurate.
Disclosure of Invention
The embodiment of the disclosure provides a method and a device for detecting a shale oil and gas reservoir protection effect, which can provide reliable basis for the shale oil reservoir protection effect. The technical scheme is as follows:
the embodiment of the disclosure provides a detection method for a shale oil and gas reservoir protection effect, which comprises the following steps:
manufacturing a first rock sample based on a shale oil and gas reservoir to be tested, and drying the first rock sample to constant weight;
manufacturing a second rock sample based on the shale oil gas reservoir to be tested, wherein the second rock sample is identical to the first rock sample in appearance, the difference value between the permeability of the second rock sample and the permeability of the first rock sample is smaller than a preset threshold value, soaking the second rock sample by using an aqueous solution of a treating agent to be tested, and drying the second rock sample to constant weight;
obtaining a first imbibition amount and a second imbibition amount, wherein the first imbibition amount is the imbibition amount of the first rock sample to the drilling fluid filtrate, and the second imbibition amount is the imbibition amount of the second rock sample to the drilling fluid filtrate;
and detecting and obtaining the protection effect of the aqueous solution of the treating agent to be detected on the shale oil-gas reservoir to be detected according to the first imbibition amount and the second imbibition amount.
In an implementation manner of the present disclosure, the detecting, according to the first imbibition amount and the second imbibition amount, the protection effect of the aqueous solution of the treating agent to be detected on the shale oil-gas reservoir to be detected includes:
and detecting the protection effect according to the difference between the first imbibition amount and the second imbibition amount, wherein the protection effect is positively correlated with the difference between the first imbibition amount and the second imbibition amount.
In another implementation of the present disclosure, fabricating a first rock sample based on a shale hydrocarbon reservoir to be tested and drying the first rock sample to constant weight, comprising:
drilling a core in the shale oil and gas reservoir to be tested, and manufacturing the first rock sample by using the core;
providing an electrothermal constant-temperature drying oven;
and drying the first rock sample to constant weight through the electric heating constant temperature drying oven.
In yet another implementation of the present disclosure, a second rock sample is made based on the shale oil and gas reservoir to be tested, the second rock sample is identical to the first rock sample in shape and the difference between the permeabilities is smaller than a preset threshold, and then soaked in an aqueous solution of a treating agent to be tested, and the second rock sample is dried to constant weight, including:
drilling a core in the shale oil and gas reservoir to be tested, and manufacturing the second rock sample by using the core;
soaking the second rock sample by the aqueous solution of the treating agent to be detected;
providing an electrothermal constant-temperature drying oven;
and drying the second rock sample to constant weight through the electric heating constant temperature drying oven.
In yet another implementation of the present disclosure, obtaining the first imbibition amount includes:
providing a detection device, wherein the detection device comprises a weighing detection instrument, a container filled with drilling fluid filtrate, a computer acquisition system and an automatic liquid level tracking system;
placing a container containing the drilling fluid filtrate on the weighing detection instrument;
fixing the first rock sample on the automatic liquid level tracking system, and keeping the bottom surface of the first rock sample above the liquid level of the drilling fluid filtrate through the automatic liquid level tracking system, wherein the bottom surface of the first rock sample is always tangent to the liquid level of the drilling fluid filtrate;
the computer acquisition system is used for acquiring the weight change value of the container of the drilling fluid filtrate obtained by the detection of the weighing detection instrument;
and calculating to obtain the first imbibition amount according to the container weight change value of the drilling fluid filtrate.
In yet another implementation of the present disclosure, the calculating the first imbibition amount according to the container weight variation value of the drilling fluid filtrate includes:
observing the change value of the weight of the container of the drilling fluid filtrate;
and if the container weight change value of the drilling fluid filtrate is kept unchanged, calculating to obtain the first seepage and suction amount according to the container weight change value of the drilling fluid filtrate at the moment.
In yet another implementation of the present disclosure, the detection apparatus includes: the automatic liquid level tracking system comprises a controller, a liquid level detector and a driving mechanism, wherein the liquid level detector is electrically connected with the controller, the liquid level detector is positioned in an opening of the container, and the driving mechanism is used for driving the first rock sample.
In yet another implementation of the disclosure, the driving mechanism includes a driving motor and a driving arm, the driving motor is located outside the container, one end of the driving arm is in transmission connection with the driving motor, and the other end of the driving arm extends into the opening of the container and is used for clamping the first rock sample or the second rock sample.
In yet another implementation of the present disclosure, the drive motor is a macro motor.
In yet another implementation of the present disclosure, the weight detection instrument is an analytical balance.
The technical scheme provided by the embodiment of the disclosure has the beneficial effects that:
according to the method for detecting the shale oil gas reservoir protection effect, when the surface wettability of the treating agent is detected, the first rock sample is manufactured based on the shale oil gas reservoir to be detected, and is dried to constant weight, and as the first rock sample is taken from the shale oil gas reservoir, the porosity and the permeability of the first rock sample are consistent with those of the shale oil gas reservoir. And manufacturing a second rock sample based on the shale oil gas reservoir to be tested, wherein the second rock sample and the first rock sample have the same appearance, the difference value between the permeability is smaller than a preset threshold value, and the second rock sample is soaked by the aqueous solution of the treating agent to be tested and then dried to constant weight. Because the second rock sample and the first rock sample are both taken from the same shale oil gas reservoir to be tested, and the second rock sample is identical to the first rock sample in appearance, the difference between the permeability of the second rock sample and the first rock sample is smaller than a preset threshold value, the porosity and the permeability of the second rock sample are basically identical to those of the first rock sample, and the difference is not great. Therefore, after the second rock sample is soaked by the aqueous solution of the treating agent, the second rock sample is compared with the first rock sample, and the difference is only whether the second rock sample is soaked by the aqueous solution of the treating agent, so that the control variable is realized, and the detection accuracy is ensured.
And then, acquiring a first imbibition amount of the first rock sample and a second imbibition amount of the second rock sample, wherein the first rock sample without soaking the aqueous solution of the treating agent and the second rock sample soaked with the aqueous solution of the treating agent can be respectively determined according to the first imbibition amount and the second imbibition amount, and the adsorption amount is when the drilling fluid filtrate is adsorbed to a saturated state. By comparing the first imbibition magnitude and the second imbibition magnitude, the adsorption amount of the drilling fluid filtrate is changed when the second rock sample soaked with the aqueous solution of the treating agent is compared with the first rock sample not soaked with the aqueous solution of the treating agent, so that the improvement of the surface wettability of the treating agent on the surface of the shale oil gas reservoir can be determined, and the protection effect of the treating agent on the shale oil gas reservoir can be detected.
According to the method for detecting the shale oil-gas reservoir protection effect, the adsorption quantity difference of the drilling fluid filtrate is detected between the second rock sample soaked in the aqueous solution of the treating agent and the first rock sample not soaked in the aqueous solution of the treating agent, the surface modification degree (improvement degree of surface wettability) of the treating agent on the shale oil-gas reservoir is visually reflected, the oil layer protection effect is evaluated, the problem of difficulty in nano pore throat protection evaluation is solved, and meanwhile a reliable basis is provided for selecting a protection method of the shale oil-gas reservoir.
Drawings
In order to more clearly illustrate the technical solutions of the embodiments of the present disclosure, the drawings required for the description of the embodiments will be briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present disclosure, and other drawings may be obtained according to these drawings without inventive effort for a person of ordinary skill in the art.
FIG. 1 is a schematic structural diagram of a detection device for shale oil and gas reservoir protection provided by an embodiment of the present disclosure;
FIG. 2 is a flow chart of a method for detecting a shale oil and gas reservoir protection effect provided by an embodiment of the present disclosure;
FIG. 3 is a flow chart of another method for detecting shale hydrocarbon reservoir protection effectiveness provided by embodiments of the present disclosure;
FIG. 4 is a graph of self-priming volume of a first rock sample provided by an embodiment of the present disclosure;
fig. 5 is a graph of the self-priming volume of a second rock sample after 3% treatment provided by an embodiment of the present disclosure.
The symbols in the drawings are as follows:
100. a weighing detection instrument; 101. a container;
200. a first rock sample; 300. a computer acquisition system;
400. an automatic liquid level tracking system; 401. a controller; 402. a liquid level detector; 403. a driving mechanism; 4031. a driving motor; 4032. a driving arm.
Detailed Description
For the purposes of clarity, technical solutions and advantages of the present disclosure, the following further details the embodiments of the present disclosure with reference to the accompanying drawings.
Fig. 1 is a schematic structural diagram of a detection device for shale oil and gas reservoir protection effect according to an embodiment of the present disclosure, and in combination with fig. 1, the detection device includes: the automatic liquid level tracking system 400 comprises a controller 401, a liquid level detector 402 and a driving mechanism 403, wherein the liquid level detector 402 is electrically connected with the controller 401, the liquid level detector 402 is positioned in an opening of the container 101, and the driving mechanism 403 is used for driving the first rock sample 200 or the second rock sample to move along the liquid level direction perpendicular to the drilling liquid filtrate.
In the above implementation manner, the container 101 filled with the drilling fluid filtrate can be weighed by the weighing detection instrument 100, so that the total weight of the first rock sample 200 or the second rock sample in the container 101 of the drilling fluid filtrate is known before the drilling fluid filtrate is imbibed, the computer acquisition system 300 can record the displayed data in the weighing detection instrument 100 in real time, so as to track the detection result in real time, know the data change in the detection process, ensure the readiness of experimental data, and also conveniently record the experimental result. The automatic liquid level tracking system 400 can automatically control the position height of the first rock sample or the second rock sample, ensures that the bottom surface of the first rock sample or the second rock sample is always contacted with the liquid level of the drilling fluid filtrate when detection is carried out, so that the first rock sample or the second rock sample can fully dialyze the drilling fluid filtrate, and the accuracy of experiments is improved. Therefore, through the detection device, the seepage and absorption condition of the first rock sample or the second rock sample to the drilling fluid filtrate can be automatically detected, and the detection efficiency and the reliability of detection data are improved.
Optionally, the driving mechanism 403 includes a driving motor 4031 and a driving arm 4032, where the driving motor 4031 is located outside the container 101, one end of the driving arm 4032 is in transmission connection with the driving motor 4031, and the other end of the driving arm 4032 extends into the opening of the container 101 and is used for clamping the first rock sample 200 or the second rock sample.
In the above implementation manner, the driving arm 4032 is used for clamping the first rock sample or the second rock sample, the contact of the liquid level detector 402 is in contact with the liquid level of the drilling fluid filtrate, so as to detect the liquid level of the drilling fluid filtrate in the container 101, and feed back the liquid level to the controller 401 in real time, and the controller 401 adjusts the heights of the driving motor 4031 and the driving arm 4032 in real time according to the feedback result, so that in the detection process, the bottom surface of the first rock sample or the second rock sample is always tangent to the liquid level of the drilling fluid filtrate, and the accuracy of the detection result is improved.
Illustratively, the drive motor 4031 may be a macro motor. The first rock sample 200 is fixed to a fixed rod of a macro motor.
Illustratively, the weight detecting instrument 100 may be an analytical balance.
In the above implementation, the analytical balance has a high sensitivity coefficient and high detection accuracy, so that the reduction value of the drilling fluid filtrate in the container 101 can be accurately detected.
Illustratively, the vessel 101 is a 100ml profiled glass cup and contains 50ml of drilling fluid filtrate therein.
In the implementation manner, by installing the drilling fluid filtrate in the glass cup, whether each detecting instrument is in place in the detection process or not can be directly observed, and the reduction of the drilling fluid filtrate and the wetting condition of the first rock sample or the second rock sample can be observed. It will be appreciated that the specifications of the container 101 may be selected according to the actual test sample, or a 250ml shaped glass may be selected, and 150ml drilling fluid filtrate is contained therein. This embodiment is not limited thereto.
The embodiment of the disclosure also provides a method for detecting the protection effect of the shale oil and gas reservoir, as shown in fig. 2, the method comprises the following steps:
s101: and manufacturing a first rock sample based on the shale oil and gas reservoir to be tested, and drying the first rock sample to constant weight.
In the implementation manner, the first rock sample is taken from the shale oil and gas reservoir to be detected, so that the porosity, permeability and other physical quantities of the first rock sample are consistent with those of the shale oil and gas reservoir to be detected, and the reliability of the detection method is improved.
S102: and manufacturing a second rock sample based on the shale oil gas reservoir to be tested, wherein the second rock sample is identical to the first rock sample in appearance, the difference value between the permeability of the second rock sample and the permeability of the first rock sample is smaller than a preset threshold value, then soaking the second rock sample by using the aqueous solution of the treating agent to be tested, and drying the second rock sample to constant weight.
In the above implementation, the first rock sample is also taken from the shale oil and gas reservoir to be tested, so that the physical quantities of the second rock sample, such as porosity, permeability, etc., are consistent with the maintenance of the shale oil and gas reservoir to be tested. And moreover, the appearance of the second rock sample is the same with that of the first rock sample, and the difference value between the permeabilities is smaller than a preset threshold value, so that the basic parameters of the second rock sample and the first rock sample can be ensured to be consistent, and the protection effect of the treating agent on the shale oil-gas reservoir to be detected is accurately known by controlling the variables when the second rock sample is compared with the first rock sample.
Illustratively, the difference between the permeability of the second rock sample and the first rock sample is less than a preset threshold, which may generally be 5mD for the shale hydrocarbon reservoir. It can be appreciated that the setting of the preset threshold value can be set according to the structural characteristics of the shale oil and gas reservoir to be detected, and in the detection process, only the small difference of the permeability and the porosity between the first rock sample and the second rock sample is ensured.
S103: and obtaining a first imbibition amount and a second imbibition amount, wherein the first imbibition amount is the imbibition amount of the first rock sample to the drilling fluid filtrate, and the second imbibition amount is the imbibition amount of the second rock sample to the drilling fluid filtrate.
In the implementation manner, the imbibition condition of the first rock sample to the drilling fluid filtrate can be known through the first imbibition quantity and the second imbibition quantity, and the imbibition condition of the second rock sample to the drilling fluid filtrate can indirectly obtain the surface wettability of the first rock sample and the second rock sample.
S104: and detecting according to the first imbibition amount and the second imbibition amount to obtain the protection effect of the aqueous solution of the treating agent to be detected on the shale oil-gas reservoir to be detected.
According to the method for detecting the shale oil gas reservoir protection effect, when the surface wettability of the treating agent is detected, the first rock sample is manufactured based on the shale oil gas reservoir to be detected, and the first rock sample is dried to constant weight, and as the first rock sample is taken from the shale oil gas reservoir, the porosity and the permeability of the first rock sample are consistent with those of the shale oil gas reservoir. And manufacturing a second rock sample based on the shale oil gas reservoir to be tested, wherein the second rock sample and the first rock sample have the same appearance, the difference value between the permeability is smaller than a preset threshold value, and the second rock sample is soaked in the aqueous solution of the treating agent to be tested and then dried to constant weight. Because the second rock sample and the first rock sample are both taken from the same shale oil gas reservoir to be tested, and the second rock sample is identical to the first rock sample in appearance, the difference between the permeability of the second rock sample and the first rock sample is smaller than a preset threshold value, the porosity and the permeability of the second rock sample are basically identical to those of the first rock sample, and the difference is not great. Therefore, after the second rock sample is soaked by the aqueous solution of the treating agent, the second rock sample is compared with the first rock sample, and the difference is only whether the second rock sample is soaked by the aqueous solution of the treating agent, so that the control variable is realized, and the detection accuracy is ensured.
And then, acquiring a first imbibition amount of the first rock sample and a second imbibition amount of the second rock sample, wherein the first rock sample without soaking the aqueous solution of the treating agent and the second rock sample soaked with the aqueous solution of the treating agent can be respectively determined according to the first imbibition amount and the second imbibition amount, and the adsorption amount is when the drilling fluid filtrate is adsorbed to a saturated state. By comparing the first imbibition magnitude and the second imbibition magnitude, the adsorption amount of the drilling fluid filtrate is changed when the second rock sample soaked with the aqueous solution of the treating agent is compared with the first rock sample not soaked with the aqueous solution of the treating agent, so that the improvement of the surface wettability of the treating agent on the surface of the shale oil gas reservoir can be determined, and the protection effect of the treating agent on the shale oil gas reservoir can be detected.
According to the method for detecting the protection effect of the shale oil-gas reservoir, the adsorption quantity difference of the drilling fluid filtrate is detected between the second rock sample soaked in the aqueous solution of the treating agent and the first rock sample not soaked in the aqueous solution of the treating agent, the improvement degree of the treating agent on the surface modification degree and the surface wettability of the shale oil-gas reservoir is visually reflected, the oil layer protection effect is evaluated, the problem of difficulty in protection evaluation of the nano pore throats is solved, and meanwhile a reliable basis is provided for selection of the protection method of the shale oil-gas reservoir.
Fig. 3 is a flowchart of another method for detecting a shale oil and gas reservoir protection effect according to an embodiment of the present invention, referring to fig. 3, the method for detecting a shale oil and gas reservoir protection effect includes:
s201, drilling a core in a shale oil and gas reservoir to be tested, and manufacturing a first rock sample by using the core.
Illustratively, a core is drilled in a corresponding target detection zone in a shale hydrocarbon reservoir by a coring tool, and then a first rock sample is fabricated in the core by a prototype drill. The first rock sample was of cylindrical configuration, 2.5cm in diameter, 7cm in length and 0.83mD in permeability.
S202, providing an electric heating constant temperature drying oven.
For example, the corresponding drying temperature of the electrothermal constant temperature drying oven may be set to 105±3 ℃.
And S203, drying the first rock sample to constant weight through an electric heating constant temperature drying oven.
In the above implementation manner, the electrothermal constant temperature drying oven may dry the first rock sample to a constant weight, so as to ensure that the moisture in the first rock sample is driven out, so as to implement step S207.
The steps S201-S203 can be used for manufacturing the first rock sample based on the shale oil and gas reservoir to be tested, and drying the first rock sample to constant weight.
S204, drilling a core in the shale oil and gas reservoir to be tested, and manufacturing a second rock sample by using the core, wherein the second rock sample has the same appearance as the first rock sample, and the difference value between the permeability of the second rock sample and the permeability of the first rock sample is smaller than a preset threshold value.
In the implementation manner, the first rock sample and the second rock sample are taken from the shale oil gas reservoir to be detected, so that the physical properties of the first rock sample and the second rock sample can be kept consistent as much as possible, the first rock sample is used as a blank experiment group and is compared with the second rock sample, and the accuracy of the detection method is further guaranteed.
Alternatively, a second rock sample may also be made from the core drilled in step S201. Namely, a first rock sample is manufactured by using one part of the core, and a second rock sample is manufactured by using the rest of the core. That is, the first rock sample and the second rock sample are both manufactured by using the same rock core, so that the physical properties of the first rock sample and the second rock sample can be better ensured to be consistent.
Illustratively, the second rock sample is of cylindrical configuration, 2.5cm in diameter, 7cm in length, and 0.91mD in permeability.
S205, soaking the second rock sample by the aqueous solution of the treating agent to be detected.
In the above implementation, the treating agent may change the surface wettability of the second rock sample, and the surface wettability of the second rock sample may be changed after the second rock sample is treated with the treating agent. In general, the shale oil and gas reservoir after being treated by the treating agent has reversed surface wettability, that is, the surface wettability is weakened, so that the shale oil and gas reservoir is prevented from being damaged by the drilling fluid during drilling. Therefore, the wettability of shale hydrocarbon reservoirs is typically modified by a treating agent to protect the shale hydrocarbon reservoir.
Illustratively, the aqueous solution of the treating agent to be tested is an aqueous solution containing 3% of the treating agent.
S206, providing an electric heating constant temperature drying oven, and drying the second rock sample to constant weight through the electric heating constant temperature drying oven.
In the above implementation manner, the electrothermal constant temperature drying oven may dry the second rock sample to a constant weight, so as to ensure that the moisture in the second rock sample is driven out, so as to implement step S207.
It should be noted that the electrothermal constant temperature drying oven for drying the second core can be the same as the electrothermal constant temperature drying oven for drying the first core, so that the purchase cost of the testing equipment can be reduced.
The step S204-S206 can be used for manufacturing a second rock sample based on the shale oil gas reservoir to be tested, the second rock sample and the first rock sample are identical in appearance, the difference value between the permeability is smaller than a preset threshold value, the second rock sample is soaked in the aqueous solution of the treating agent to be tested, and the second rock sample is dried to constant weight.
S207: and obtaining a first imbibition amount and a second imbibition amount, wherein the first imbibition amount is the imbibition amount of the first rock sample to the drilling fluid filtrate, and the second imbibition amount is the imbibition amount of the second rock sample to the drilling fluid filtrate.
Alternatively, the obtaining of the first imbibition amount may be achieved by:
first, a detection apparatus as shown in fig. 1 is provided, which includes a weight detection instrument 100, a container 101 containing drilling fluid filtrate, a computer acquisition system 300, and an automatic level tracking system 400.
Next, the container 101 containing the drilling fluid filtrate is placed on the weight detecting instrument 100;
in the above implementation, the weight of the container 101 containing the drilling fluid filtrate may be measured by the weight measuring apparatus 100, so that the weight of the container 101 of the drilling fluid filtrate is known before the first rock sample 200 is imbibed with the drilling fluid filtrate.
Then, the first rock sample is fixed on an automatic liquid level tracking system, the bottom surface of the first rock sample is kept above the liquid level of the drilling fluid filtrate through the automatic liquid level tracking system, and the bottom surface of the first rock sample is always tangent to the liquid level of the drilling fluid filtrate.
In the implementation mode, the position of the first rock sample is controlled, so that the bottom surface of the first rock sample is always tangent to the liquid level of the drilling fluid filtrate, and the first rock sample is ensured to be capable of sucking the drilling fluid filtrate until reaching saturation.
And secondly, acquiring the weight change value of the container of the drilling fluid filtrate by the detection of a weighing detection instrument through a computer acquisition system.
The computer acquisition system 300 can record the displayed data in the weighing detection instrument 100 in real time, further track the experimental result in real time, know the data change in the experimental process, ensure the readiness of the experimental data, and conveniently record the experimental result.
And finally, calculating to obtain a first imbibition amount according to the weight change value of the container of the drilling fluid filtrate.
In the above implementation, the change in the weight of the container of drilling fluid filtrate is a decrease in the value, which is due to the imbibition of the drilling fluid filtrate by the first rock sample.
Illustratively, the first suction capacity is calculated according to the change value of the weight of the container of the drilling fluid filtrate, and the first suction capacity can be realized by the following steps:
step one: the change in the weight of the vessel of drilling fluid filtrate was observed.
In the above implementation manner, since the first rock sample is an inorganic mixture, and the surface of the first rock sample has strong wettability, the first rock sample can automatically imbibe the drilling fluid filtrate, but the imbibition process can gradually decrease along with the extension of time, so that the container weight change value of the drilling fluid filtrate needs to be observed at any time, so that the smooth proceeding in the detection process can be ensured.
Step two: if the container weight change value of the drilling fluid filtrate is kept unchanged, calculating to obtain a first seepage and suction amount according to the container weight change value of the drilling fluid filtrate at the moment.
In the above implementation manner, after the first rock sample passes through the fixed time, the imbibition of the drilling fluid filtrate can reach saturation, and correspondingly, the container weight change value of the drilling fluid filtrate is kept unchanged, and at this time, the first imbibition amount can be known by calculating the container weight change value of the drilling fluid filtrate.
It should be noted that the above data are all directly read by observing the computer acquisition system.
Alternatively, the obtaining of the second imbibition amount may be achieved by:
and taking down the first rock sample, replacing the first rock sample with a second rock sample, fixing the second rock sample on an automatic liquid level tracking system, and keeping the bottom surface of the second rock sample above the liquid level of the drilling fluid filtrate through the automatic liquid level tracking system, wherein the bottom surface of the second rock sample is always tangent to the liquid level of the drilling fluid filtrate.
In the implementation mode, the bottom surface of the second rock sample is always tangent to the liquid level of the drilling fluid filtrate by controlling the position of the second rock sample, so that the second rock sample can be guaranteed to be capable of sucking the drilling fluid filtrate until the drilling fluid filtrate is saturated.
And secondly, acquiring the weight change value of the container of the drilling fluid filtrate by the detection of a weighing detection instrument through a computer acquisition system.
The computer acquisition system can record the displayed data in the analytical balance in real time, further track the experimental result in real time, know the data change in the experimental process, ensure the readiness of the experimental data, and conveniently record the experimental result.
And finally, calculating to obtain a second seepage and suction amount according to the weight change value of the container of the drilling fluid filtrate.
In the above implementation, the change in the weight of the container of drilling fluid filtrate is a decrease in the value, which is due to the imbibition of the drilling fluid filtrate by the second rock sample.
Illustratively, the second suction capacity is calculated according to the change value of the weight of the container of the drilling fluid filtrate, and the second suction capacity can be realized by the following steps:
step one: the change in the weight of the vessel of drilling fluid filtrate was observed.
Step two: if the container weight change value of the drilling fluid filtrate is kept unchanged, calculating to obtain a first seepage and suction amount according to the container weight change value of the drilling fluid filtrate at the moment.
The above methods are consistent with the detection process in the first rock sample and will not be described here again.
And S208, detecting and obtaining the protection effect of the aqueous solution of the treating agent to be detected on the shale oil-gas reservoir to be detected according to the first imbibition amount and the second imbibition amount.
Alternatively, S208 may be implemented by:
and detecting according to the difference between the first imbibition amount and the second imbibition amount to obtain a protection effect, wherein the protection effect is positively correlated with the difference between the first imbibition amount and the second imbibition amount.
It should be noted that this positive correlation means that the larger the difference between the first imbibition amount and the second imbibition amount, the larger the capability of the treatment agent to change the surface wettability of the second rock sample. Conversely, the smaller.
In the above implementation manner, when the second imbibition amount is not smaller than the first imbibition amount, it is determined that the capability of the treating agent to change the surface wettability of the second rock sample is weak, that is, the treating agent does not reverse the surface wettability of the second rock sample, that is, the treating agent does not weaken the surface wettability of the second rock sample, which means that the effect of the treating agent on protecting the shale oil-gas reservoir is weak, and when the second imbibition amount is zero or the second imbibition amount is smaller than the first imbibition amount, it is determined that the capability of the treating agent to change the surface wettability of the second rock sample is strong, that is, the treating agent can reverse the surface wettability of the second rock sample, that is, the treating agent can weaken the surface wettability of the second rock sample, which means that the effect of the treating agent on protecting the shale oil-gas reservoir is strong.
In order to further illustrate the specific implementation steps of the method for detecting the shale oil and gas reservoir protection effect in the present disclosure, the following actual detection is performed:
1 preparing a first rock sample and a second rock sample.
(1) A piece of shale with the diameter of 2.5cm and the permeability of 7cm and the length of 0.83mD is taken as a first rock sample to be put into an electrothermal constant-temperature drying oven with the temperature of 105+/-3 ℃ and dried to constant weight.
(2) And (3) taking the other shale with the diameter of 2.5cm and the permeability of 7cm and the permeability of 0.91mD as a second rock sample, treating the second rock sample by using a 3% aqueous solution of a treating agent, putting the second rock sample into an electrothermal constant-temperature drying oven at 105+/-3 ℃, and drying the second rock sample until the weight is constant.
2, detection process.
The filtrate containing 50mL of drilling fluid is added into a specially-manufactured 100mL special glass.
The first rock sample is fixed on a driving arm of an automatic liquid level tracking system, and a liquid level detector is fixed at the same time, so that the lower end of the liquid level detector contacts the liquid level, and the first rock sample is above the liquid level of drilling fluid filtrate. And adjusting a controller of the automatic liquid level tracking system to enable the first rock sample to slowly descend. When the bottom surface of the first rock sample is tangent to the liquid level of the drilling fluid filtrate, an automatic control button of a controller of the automatic liquid level tracking system is started, and meanwhile, a computer acquisition system is started, and weight data of the analysis balance, which change with time, are automatically recorded through the computer acquisition system, wherein a imbibition curve of the first rock sample is shown in fig. 4 in the detection process. After the detection of the first rock sample is finished, the imbibition condition of the second rock sample treated by the 3% treating agent aqueous solution to the drilling fluid filtrate is measured by the same method, wherein the imbibition quantity curve of the second rock sample is shown in fig. 5.
(3) Conclusion of the experiment
From fig. 4 and fig. 5, it can be seen that the shale core from the same rock is reduced from 2.52g to 0.70g in about 10min when the self-priming water amount of the second rock sample treated by the treating agent is continuously absorbed to 60min, which indicates that the treating agent can successfully modify the rock on the shale surface, greatly reduces the amount of filtrate entering the rock, and has better effect of protecting the hydrocarbon reservoir.
The foregoing is merely an alternative embodiment of the present disclosure, and is not intended to limit the present disclosure, any modification, equivalent replacement, improvement, etc. that comes within the spirit and principles of the present disclosure are included in the scope of the present disclosure.
Claims (9)
1. The method for detecting the shale oil and gas reservoir protection effect is characterized by comprising the following steps of:
drilling a core in a corresponding target detection layer in a shale oil and gas reservoir by using a core drilling tool, manufacturing a first rock sample in the core by using a sample drilling machine, and drying the first rock sample to constant weight, wherein the first rock sample is of a cylindrical structure;
drilling a core in a shale oil-gas reservoir to be tested, manufacturing a second rock sample by using the core, wherein the second rock sample is identical to the first rock sample in appearance, the difference value between the permeability of the second rock sample and the permeability of the first rock sample is smaller than a preset threshold value, soaking the second rock sample by using an aqueous solution of a treating agent to be tested, and drying the second rock sample to constant weight;
obtaining a first imbibition amount and a second imbibition amount, wherein the first imbibition amount is the imbibition amount of the first rock sample to the drilling fluid filtrate, and the second imbibition amount is the imbibition amount of the second rock sample to the drilling fluid filtrate;
and detecting the protection effect according to the difference between the first imbibition amount and the second imbibition amount, wherein the protection effect is positively correlated with the difference between the first imbibition amount and the second imbibition amount.
2. The method of testing of claim 1, wherein fabricating a first rock sample based on a shale hydrocarbon reservoir to be tested and drying the first rock sample to a constant weight comprises:
drilling a core in the shale oil and gas reservoir to be tested, and manufacturing the first rock sample by using the core;
providing an electrothermal constant-temperature drying oven;
and drying the first rock sample to constant weight through the electric heating constant temperature drying oven.
3. The method of testing according to claim 1, wherein creating a second rock sample based on the shale hydrocarbon reservoir to be tested, the second rock sample being the same in shape as the first rock sample and having a difference in permeability less than a predetermined threshold, then soaking the second rock sample with an aqueous solution of a treating agent to be tested and drying the second rock sample to a constant weight, comprises:
soaking the second rock sample by the aqueous solution of the treating agent to be detected;
providing an electrothermal constant-temperature drying oven; and drying the second rock sample to constant weight through the electric heating constant temperature drying oven.
4. The method of detecting according to claim 1, wherein obtaining the first imbibition amount comprises:
providing a detection device, wherein the detection device comprises a weighing detection instrument, a container filled with drilling fluid filtrate, a computer acquisition system and an automatic liquid level tracking system;
placing a container containing the drilling fluid filtrate on the weighing detection instrument;
fixing the first rock sample on the automatic liquid level tracking system, and keeping the bottom surface of the first rock sample above the liquid level of the drilling fluid filtrate through the automatic liquid level tracking system, wherein the bottom surface of the first rock sample is always tangent to the liquid level of the drilling fluid filtrate;
the computer acquisition system is used for acquiring the weight change value of the container of the drilling fluid filtrate obtained by the detection of the weighing detection instrument;
and calculating to obtain the first imbibition amount according to the container weight change value of the drilling fluid filtrate.
5. The method according to claim 4, wherein the calculating the first imbibition amount according to the container weight variation value of the drilling fluid filtrate comprises:
observing the change value of the weight of the container of the drilling fluid filtrate;
and if the container weight change value of the drilling fluid filtrate is kept unchanged, calculating to obtain the first seepage and suction amount according to the container weight change value of the drilling fluid filtrate at the moment.
6. A detection device for shale oil and gas reservoir protection effect, characterized in that the detection device is used for the detection method as claimed in any one of claims 1-4, the detection device comprising:
the automatic liquid level tracking system (400) comprises a controller (401), a liquid level detector (402) and a driving mechanism (403), wherein the liquid level detector (402) is electrically connected with the controller (401), the liquid level detector (402) is located in an opening of the container (101), and the driving mechanism (403) is used for driving the first rock sample (200) or the second rock sample to move along the liquid level direction perpendicular to the drilling liquid filtrate.
7. The detection device according to claim 6, wherein the driving mechanism (403) comprises a driving motor (4031) and a driving arm (4032), the driving motor (4031) is located outside the container (101), one end of the driving arm (4032) is in transmission connection with the driving motor (4031), and the other end of the driving arm (4032) extends into the opening of the container (101) and is used for clamping the first rock sample (200) or the second rock sample.
8. The detection device according to claim 7, wherein the drive motor (4031) is a macro motor.
9. The detection device according to claim 6, characterized in that the weighing detection instrument (100) is an analytical balance.
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| CN104849765B (en) * | 2009-12-16 | 2017-10-24 | 英国石油勘探运作有限公司 | method for measuring rock wettability |
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| CN101196460A (en) * | 2007-10-26 | 2008-06-11 | 辽河石油勘探局 | Appraisement method for rock wettability |
| CN105092404A (en) * | 2014-05-14 | 2015-11-25 | 中国石油天然气股份有限公司 | Self-priming experimental instrument and experiment detection method |
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