CN116816334A - High-temperature and high-pressure water invasion experimental method for gas reservoirs considering different gas-water distribution modes - Google Patents
High-temperature and high-pressure water invasion experimental method for gas reservoirs considering different gas-water distribution modes Download PDFInfo
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- 230000009545 invasion Effects 0.000 title claims abstract description 66
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- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims abstract description 94
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- 239000011229 interlayer Substances 0.000 claims description 67
- 238000011084 recovery Methods 0.000 claims description 27
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/10—Locating fluid leaks, intrusions or movements
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium
- E21B43/168—Injecting a gaseous medium
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Abstract
The invention belongs to the field of oil and gas field development engineering, and particularly relates to a gas reservoir high-temperature high-pressure water invasion experimental method considering different gas-water distribution modes, which comprises the following steps: taking carbonate rock, manually making a seam, drilling a core, extracting and depicting a partition layer, using high-temperature resistant resin to score an impermeable partition layer, placing the impermeable partition layer between two split core halves, and loading the impermeable partition layer into a core holder. Applying confining pressure to core holder P 0 The method comprises the steps of carrying out a first treatment on the surface of the Injecting inert gas to displace air; natural gas is injected, inert gas is displaced, and the gas composition is determined. Controlling the confining pressure to be stabilized at P 0 The formation water is processed according to the formation pressure P i Injecting core holder from inlet end, regulating pressure P i Down to P 3 Separating gas and water by a separator, and measuring the cumulative gas volume V i And accumulated water yield W i . And recording the water outlet time until the outlet end produces water completely. Calculating constant pressure stratum water invasion stageRecovery ratio R w Determining the density of formation water as rho, and calculating the water content ƒ of the constant-pressure formation water invasion stage w 。
Description
Technical Field
The invention belongs to the field of oil and gas field development engineering, and particularly relates to a gas reservoir high-temperature high-pressure water invasion experimental method considering different gas-water distribution modes.
Background
According to statistics, more than 95% of carbonate reservoirs developed in Sichuan basin have side water and bottom water, and gas-water two-phase flow is ubiquitous in the reservoir formation and development processes. The side and bottom water invasion easily occurs in the open process of the gas reservoir, so that gas-water two-phase seepage is formed in the reservoir, the seepage resistance is greatly increased, and the recovery ratio of the gas reservoir is lowered. In particular, the gas reservoirs represented by the Yuan-dam Changxing group have complex gas-water relationship, and stratum water distribution modes can be divided into a layer-type (main type) and a layer-free type according to the occurrence relationship of gas and water, and water invasion rules under different gas-water distribution modes are different.
For gas reservoir water invasion, three water control technologies have been developed in the prior art: plugging water in gas reservoirs, draining water, producing gas, and controlling water by production allocation. The main functions of production allocation, water control, drainage and gas production are to delay the water invasion of the gas reservoir, and the water blocking method of the gas reservoir is to control the invasion of bottom water. In 2016, yang Zhixing et al proposed "a water flooding profile model seepage simulation experiment of a sidewater sandstone gas reservoir" (chinese patent CN109519156 a), which adopts a physical flat plate filling model, and adds an impermeable baffle plate as a interlayer to make the model more approximate to the geological condition of an actual gas reservoir, so as to simulate the water propulsion situation in the development process of the sidewater gas reservoir, and analyze the influence of the water on the recovery rate of the gas reservoir. Similarly, in 2020, xue Baoqing et al, an inversion method and an inversion device for a water invasion process of a heterogeneous reservoir high-water-content horizontal well are invented (Chinese patent CN 202011238739.8), a physical model and a mathematical model are built according to the water invasion characteristics of the reservoir, and a barrier layer is correspondingly placed in the physical model according to the actual barrier layer position of the reservoir. However, the variety of formation intervals limits the applicability and range of applicability of the two experimental devices and methods.
In 2018, sun Renyuan and the like, a novel visual simulation device for oil reservoir side water invasion taking well pattern influence into consideration (China patent CN 103967460B) is disclosed, a sand filling model with an annular sand filling partition plate is used, side water invasion holes are uniformly distributed on the periphery, oil water movement streamlines and residual oil enrichment positions in a simulated reservoir can be clearly observed by using the device, different well pattern development simulations can be realized, but the artificially manufactured side water invasion holes are difficult to represent stratum pores, and experimental results are influenced to a certain extent.
Because of the changeable types of stratum and the complexity of water invasion conditions, the experimental research on the water invasion of the gas reservoir under different gas-water distribution modes is difficult, the application range of the existing experimental method is limited, the accuracy of experimental results is low, and the development of water control technology in the gas reservoir exploitation process is severely limited.
Disclosure of Invention
The invention aims to solve the problems of more limit and low accuracy of gas reservoir water invasion experiments in the prior art, and provides a gas reservoir high-temperature high-pressure water invasion experiment method considering different gas-water distribution modes.
In order to achieve the above object, the present invention provides the following technical solutions:
a gas reservoir water invasion experimental method with different gas-water distribution modes comprises the following steps:
s1, preparing a rock core: taking carbonate rock, manually making a joint, then drilling a core, and ensuring that the drilled core passes through the manual joint making structure.
And extracting and engraving the interlayer to manufacture an engraving model graph.
And carving the interlayer according to the carving model graph by using high-temperature resistant resin.
S2, installing a rock core: the septum was placed in the middle of the split core halves and then placed in the core holder.
S3, stratum pressure environment debugging: applying confining pressure to the core holder to enable the confining pressure to reach P 0 ；
Injecting inert gas to displace air in the system; injecting natural gas, and displacing the injected inert gas in the core holder until the natural gas escapes from the separator.
And (3) reversing the inlet end and the outlet end of the core holder, injecting natural gas, displacing the residual inert gas in the core holder until only the natural gas escapes from the separator, and measuring the gas composition.
S4, stratum water failure water invasion: controlling the confining pressure to be stabilized at P 0 The formation water is processed according to the formation pressure P i Injecting the core holder from the inlet end, and realizing pressure P through regulating the back pressure valve i Down to P 3 Separating gas and water by a separator, and measuring the cumulative gas volume V i And accumulated water yield W i The method comprises the steps of carrying out a first treatment on the surface of the And recording the water outlet time until the outlet end produces water completely.
S5, calculating recovery ratio: calculating recovery ratio R of constant-pressure stratum water invasion stage w Determining the density of formation water as rho, and calculating the water content d of the constant-pressure formation water invasion stage w 。
Wherein, the rock core holder is arranged in a constant temperature oven.
According to the method, the gas reservoir water invasion experimental methods with different gas water distribution modes are considered, the rock core holder is controlled to realize different confining pressures, stratum temperatures and other parameter changes, the simulation of various different pressure and water invasion scenes can be realized in the stratum pressure environment debugging process, the confining pressures are adjustable, the natural gas injection process is controllable, the environment temperature is selectable, and the influence of the gas reservoirs with different gas water distribution modes of the interlayer on the gas reservoir water invasion can be simulated. The water invasion experimental method provided by the invention can simulate the gas reservoir high-temperature high-pressure water invasion experiments with different gas-water distribution modes, and the experimental result has more practical guiding significance.
And S3, judging that the inert gas in the separator is completely displaced by measuring the gas composition, and completing the displacement of the inert gas by the natural gas when only the natural gas escapes.
In step S1, a block-shaped carbonate rock sample is taken, an artificial natural single seam is created, a cylindrical full-diameter core is drilled by a drill bit, and cleaning and drying treatment is performed. A natural single seam is created artificially, a natural seam is formed by destroying a carbonate rock sample, then a drill bit is used for drilling a circle center, for example, the drill bit is used for taking a core in a direction similar to a vertical seam, and a core sample with an experimental seam is obtained. Therefore, the finally drilled core can be broken into two parts by artificial joint, when the interlayer is placed in the drilled core, the interlayer is positioned in the split core, and the two parts of core bags clamp the interlayer in the center and then are placed in the core holder to form a simulation sample.
In step S1, the interlayer is extracted and carved, the interlayer is carved according to the artificial joint structure of the core obtained by drilling, and the carved model graph is manufactured according to the artificial joint structure on the core obtained by drilling.
Preferably, in step S1, the volume V, the porosity Φ, and the absolute permeability of the core are measured, and the core pore volume V is calculated p 。
Further, in step S1, the volume V of formation water is prepared ws ：
V ws ＝V p /B w
wherein ,Vp Pore volume of core, B w Is the volume coefficient of formation water under the current formation pressure, B w ＝1.02～1.03。
Further, in step S1, the volume V of natural gas under ground conditions is prepared gs ：
V gs ＝V p /B gi
wherein ,Vp Pore volume of core, B gi =natural gas volume coefficient at original formation pressure, B gi = 0.00212 to 0.00253. The natural gas volume is calculated according to the above formula under the ground condition. During the experiment, the natural gas is compressed when receiving the formation pressure, soA certain margin is required to be prepared by conversion, and the natural gas consumption required to be prepared is obtained according to the above calculation formula.
In step S1, the thickness of the carved interlayer is adjustable and is selected to be 1-6cm. For example, 2cm, 4cm, 6cm, etc. can be used.
Preferably, the barrier layer may be an impermeable barrier layer, a semi-permeable barrier layer or a semi-closed barrier layer. According to the experimental purposes, the corresponding interlayer is selected for experiments, so that the gas reservoir water invasion experiment under different stratum conditions can be studied.
Preferably, the impermeable interlayer is a complete interlayer, and after the interlayer is placed in the middle of the split two core halves, the two core halves can be completely blocked.
Preferably, the semi-permeable spacer is a spacer structure having a permeability lower than that of the core sample.
Preferably, the semi-closed spacer layer is capable of partially blocking two halves of the core sample.
In step S2, the manually prepared full-diameter core is split axially in half, then the interlayer is placed between the split two half full-diameter cores, the core and the interlayer are fixed by tape winding, and the two half full-diameter cores and the interlayer are integrally placed into the holder. Preferably, the adhesive tape is a high temperature and high pressure resistant adhesive tape.
Further, in step S3, the inlet end of the core holder is connected with the inert gas storage container, the natural gas storage container and the formation water storage container in parallel, and the inert gas, the natural gas or the formation water in the storage container is independently or together driven into the core holder by the driving device.
Preferably, the inert gas storage vessel, natural gas storage vessel and formation water storage vessel are placed in a thermostatted oven. The storage container is placed in the constant-temperature oven, and inert gas, natural gas and formation water are preheated or cooled, so that when the core holder is tested, the gas-liquid temperature is stable, and the temperature condition of the action of water and gas in the formation environment is simulated.
Further, the inert gas is nitrogen and/or argon. Preferably nitrogen, is inexpensive and readily available, and does not affect the test results.
Further, in step S3, the core holder is connected to a confining pressure pump, and the confining pressure parameter of the core holder is adjusted and controlled by the confining pressure pump.
Further, in step S3, the outlet end of the core holder is connected to a back pressure valve, and the back pressure valve is connected to a back pressure pump and a separation pipeline.
Preferably, the separation pipeline comprises a separator, a gas meter and a chromatograph which are connected in sequence.
Further, in step S4, the confining pressure P 0 Formation pressure P i . Preferably, P 0 -P i > 3MPa. Preferably, P 0 -P i =4-6 MPa, i.e. the confining pressure P0 is about 5MPa higher. In the shale gas reservoir exploitation process, exploitation is common by combining the empirical stratum pressure and the surrounding pressure difference of about 5MPa, and the exploitation is used for compressing natural gas and stratum water under the condition that the accuracy of experimental results is affected by the pressure difference which is too high or too low.
Further, in step S4, the back pressure valve pressure is controlled to gradually decrease by the back pressure pump. And simulating the effective air pressure reducing and changing process in the natural gas exploitation process.
Preferably, the pressure gas production volume V of each stage is measured by a gas meter i And water production volume W i 。
Further, in step S5, the recovery ratio R of the constant pressure stratum water invasion stage is calculated w ：
R w ＝V i /V gs
R w Is the recovery ratio of constant pressure stratum water invasion stage, V gs The volume of natural gas under the ground condition is V, and the gas production volume is V;
further, in step S5, the water content d of the constant pressure stratum water invasion stage is calculated w ：
d w ＝W i /(V ws ·ρ)
d w The water content of the constant-pressure stratum water invasion stage is Wi, the water production volume is V ws Is the volume of formation water and ρ is the formation water density.
Compared with the prior art, the invention has the beneficial effects that:
1. according to the method, the high-temperature high-pressure water invasion experimental methods of the gas reservoirs with different gas-water distribution modes are considered, multiple different pressure and water invasion scene simulations can be realized in the stratum pressure environment debugging process, the confining pressure is adjustable, the natural gas injection process is controllable, the environment temperature is selectable, and the influence of the gas reservoirs with different gas-water distribution modes of the interlayer on the gas reservoir water invasion can be simulated.
2. The device system adopted by the method comprises a constant temperature control device, can adjust the ambient temperature of the core holder and the air-water storage device, realizes adjustable and controllable ambient temperature control, realizes accurate control of different stratum pressures and different stratum temperatures under different stratum and interlayer types, can realize accurate simulation under continuously-changed temperature and pressure parameters, and can better help the improvement of the accuracy of complex-scene gas reservoir development and research.
Description of the drawings:
FIG. 1 is an experimental flow chart of a gas reservoir water invasion experimental method considering different gas water distribution modes.
Fig. 2 is a schematic view of a core holder in a state of holding a core and a spacer.
Fig. 3 is a schematic structural view of various prepared interlayers and core samples.
Fig. 4 is a graph of experimental data of a semi-permeable interlayer (2 cm) core.
Fig. 5 is a graph of experimental data of a semi-permeable interlayer (4 cm) core.
Fig. 6 is a graph of experimental data of a core of a semi-closed interlayer (2 cm).
The marks in the figure: 1-surrounding pressure pump, 2-displacement pump, 3-nitrogen intermediate container I, 6-nitrogen intermediate container II, 4-natural gas intermediate container, 5-stratum water intermediate container, 7-core holder, 8-back pressure valve, 9-back pressure gauge, 10-back pressure pump, 11-separator, 12-gasometer, 13-chromatograph, 14-oven, 27-surrounding pressure gauge, Y1-core sample, Y0-interlayer.
In the figures, 15, 16, 17, 18, 19, 20, 21, 22, 23, 24, 25, 26 are valves.
Detailed Description
The present invention will be described in further detail with reference to test examples and specific embodiments. It should not be construed that the scope of the above subject matter of the present invention is limited to the following embodiments, and all techniques realized based on the present invention are within the scope of the present invention.
Example 1
The gas reservoir high-temperature high-pressure water invasion experimental method considering different gas-water distribution modes sequentially comprises the following steps of:
1. core preparation
(1) And selecting a square carbonate rock core, artificially manufacturing a natural single seam, drilling a cylindrical full-diameter rock core by using a drill bit, and cleaning and drying.
(2) Determining that the length of the full-diameter core is 147 (mm), the diameter of the core is 100 (mm), and the volume V of the core is:
V＝(d/2) 2 ×π×l＝(10/2) 2 ×3.14×14.7＝1153.95(cm 3 )，
porosity Φ 9.26%, absolute permeability 2.49 (mD), core pore volume V p The method comprises the following steps:
V p ＝V×Φ＝1153.95×9.26％＝106.86(cm 3 )。
volume coefficient of formation water B at formation pressure w =1.02, natural gas volume coefficient B under original formation pressure conditions gi＝ 0.00212. The volume of formation water V to be disposed under the ground condition ws The method comprises the following steps:
V ws ＝V p /B w ＝106.86÷1.02＝104.76cm 3 。
volume V of natural gas at ground conditions gs The method comprises the following steps:
V gs ＝V p /B gi ＝106.86÷0.00212＝50405.67cm 3 。
(3) And extracting and finely depicting the interlayer of the target reservoir by using computer aided drawing software (such as AutoCAD), and reducing the interlayer picture to 147 (mm) multiplied by 100 (mm) to manufacture an engraving model picture.
(4) A low-temperature curing high-temperature resistant resin (epoxy resin is used in the embodiment) is used, poured into a square mould, and carboxyl-terminated liquid nitrile rubber, polysulfide rubber, liquid silicone rubber, polyether, polysulfone, polyimide, nano calcium carbonate, nano titanium dioxide and the like (a toughening agent, a reinforcing agent and a curing agent are added, the proportion of the auxiliary agent is carried out according to the use instruction provided by an epoxy resin manufacturer) are stirred and kept stand for 8 hours, so that the mixture is solidified into colloid and taken out.
And engraving an annular structure on the colloid square according to a model diagram by adopting an engraving machine, and then manufacturing a semi-permeable interlayer (2 cm and 4 cm) by utilizing a rock material with lower permeability than that of the core sample. And a half of the sample structure is made of resin materials, and the other half of the sample structure is reserved with the core sample to form a semi-closed interlayer (2 cm).
As shown in fig. 3, a is a core sample without a interlayer, and only has one artificial single seam. Wherein b and c are samples arranged in a semi-closed manner, the lower left Ki mark part is a closed structure made of a resin material, and the difference between b and c is that the lower right grid-shaped part is a sample with different permeabilities. Wherein d and e are semi-permeable samples, the core sample is divided into three sections, the middle section is processed by adopting rock with permeability lower than that of the core sample, and d and e are different in that the permeability of the rock with permeability lower than that of the core sample used in the middle section is different.
Specific structures of the semi-closed interlayer (2 cm), the semi-permeable interlayer (2 cm) and the semi-permeable interlayer (4 cm) prepared by the engraving machine are described below. The semi-closed interlayer (2 cm) is made of resin and has a lower left half-substituted structure, as shown in fig. 3 b or c, which differ in the lower right rock permeability. The semi-permeable interlayer (2 cm) and the semi-permeable interlayer (4 cm) are shown as d or e in fig. 3, the upper section and the lower section adopt different length ratios for analyzing the influence of different semi-permeable interlayers on gas reservoir water invasion, the difference between d and e is the difference of the permeability of the rock adopted in the middle part, and the rock permeability of the middle layers of d and e is smaller than that of the core sample.
(5) The manually prepared full-diameter core is split in half along the axial direction, then the interlayer is placed between the split two half full-diameter cores, the core and the interlayer are fixed by winding a high-temperature and high-pressure resistant adhesive tape, and the two half full-diameter cores and the interlayer are integrally placed in a clamp holder, as shown in fig. 2. The thickness of the interlayer refers to the thickness of the interlayer Y0 in the vertical direction of the cross section of the two core samples Y1.
2. Preparation of experiments
The experimental device system shown in fig. 1 is adopted, the device system comprises a core holder 7, and the outer side of a polytetrafluoroethylene tube of the core holder 7 is connected with a confining pressure pump 1. The confining pressure pump 1 injects hydraulic oil to the outer side of a polytetrafluoroethylene tube in the core holder, so that confining pressure adjustment control of the outer side of the core holder 7 is realized.
The inlet end of the core holder 7 is connected with a nitrogen storage container 3, a natural gas storage container 4 and a stratum water storage container 5 in parallel, the three storage containers are connected with a displacement pump 2, and the displacement pump 2 controls and regulates the storage containers to store gas or liquid to be conveyed to the inlet end of the core holder 7 according to a certain pressure.
The outlet end of the core holder 7 is connected to a back pressure valve 8 which is respectively connected with a nitrogen intermediate container II 6 and a separator 11, and the outlet of the separator is sequentially connected with a gas meter and a chromatograph.
The core holder, the nitrogen storage container, the natural gas storage container and the formation water storage container are placed in a constant temperature oven 14, and the same environmental temperature conditions are uniformly controlled.
The initial system parameters were set as follows:
(1) Nitrogen is filled in the first nitrogen intermediate container 3 and the second nitrogen intermediate container 6, natural gas is filled in the natural gas intermediate container 4, formation water is filled in the formation water intermediate container 5, a rock core with a circular interlayer and with the full diameter is placed in the long rock core holder 7, and then the rock core is placed in the constant temperature oven 14. In the schematic diagram of the system of the apparatus according to fig. 1, the apparatus is connected according to the flow, the temperature of the oven 14 is set to be the formation temperature t=160 ℃, and all valves are kept in the closed state.
(2) Back pressure setting is performed on the back pressure valves 8 by using the back pressure pumps 10, respectively, and the back pressure is set to the formation pressure P i ＝60MPa。
3. Establishing original formation conditions
(1) The confining pressure pump 1 is used for injecting hydraulic oil to the outer side of a polytetrafluoroethylene tube in the core holder, and the confining pressure is increased to P 0 ＝65(MPa)。
(2) Opening valves 16, 17, 18, 23, 25, 26, starting the displacement pump 2 and the back pressure pump 10, and setting the pressure of the displacement pump 2 to P 0 The nitrogen in nitrogen intermediate vessel one 3, nitrogen intermediate vessel two 6 was brought into the system in core holder 7 along the line =60 MPa. Valve 24 is opened until nitrogen escapes from separator 11. The valves 16, 17, 18, 23, 24, 25, 26 are closed.
(3) The valves 16, 19, 20 and 24 are opened, the displacement pump 2 is driven, and the set pressure is P 0 The natural gas in the natural gas intermediate vessel 4 was introduced into the system in the core holder 7 along the pipeline, displacing the original nitrogen until the natural gas in the separator 11 escaped, and the gas composition in the gas meter 12 was tested by the chromatograph 13.
(4) The valves 16, 19, 20, 24 are closed. The inlet end and the outlet end of the core holder 7 are exchanged, the pipelines are connected, the valves 16, 19, 20 and 24 are opened, the displacement pump 2 is driven, and the pressure P is set 0 The natural gas in the natural gas intermediate vessel 4 was brought into the system in the core holder 7 along the pipeline, the remaining nitrogen in the core holder 7 was displaced until only the natural gas in the back pressure valve 11 escaped, and the gas composition in the gas meter 12 was tested with the chromatograph 13.
4. Formation water failure water invasion
(1) Stabilizing the confining pressure at P using confining pressure pump 1 0 Using displacement pump 2 to keep the formation water intermediate vessel 5 pressure constant at formation pressure P =65 MPa i ＝60MPa。
(2) The valves 16, 21, 22, 24 are opened, and the back pressure pump 10 is synchronously used to control the pressure of the back pressure valve 8 to be 5MPa/h from P i Slowly reducing 60MPa to 15MPa, separating gas and water by using a separator 11, and measuring the pressure gas production volume V of each stage by using a gas meter 12 i And water production volume W i Specific data are shown in table 1.
TABLE 1 data of core water invasion simulation experiments of semi-permeable interlayer (2 cm)
Cumulative gas volume v= 35075 (cm) 3 ) And cumulative water yield w=25.7 (cm) 3 ). And simultaneously recording the water outlet time. Until the outlet end has produced water, the valves 16, 21, 22, 24 are closed.
The semi-permeable interlayer (2 cm) core water invasion simulation experiment data are drawn to be a graph, as shown in fig. 4, in the early stage of the failure process, the cumulative recovery rate rapidly rises, because the interlayer is in the middle, water body firstly invades the bottom reservoir layer and then is blocked by the interlayer and then invades the upper reservoir layer, so that the unit pressure drop gas production rate firstly rises and then falls and then rises until the core water is at 30MPa, the cumulative recovery rate slowly rises, and the unit pressure drop gas production rate slowly continues to fall after suddenly falling due to the fact that the water enters the gas-water co-recovery stage after water is taken in.
5. Recovery calculation
(1) Calculating final recovery ratio R of core water invasion experiment of semi-permeable interlayer (2 cm) w (％)。
Wherein V is the cumulative gas volume, V gs Is the volume of natural gas at ground conditions.
(2) Determining the density of formation water as rho (formation water) =1, and calculating the final water content d of a core water invasion experiment of a semi-permeable interlayer (2 cm) w (％)
Wherein W is the accumulated water yield, V ws Is the volume of formation water under the ground condition, and ρ is the formation water density.
Therefore, the final cumulative recovery ratio was 74.57%, and the final water content f was 24.53%.
Example 2
Experiments were performed using the semi-permeable interlayer (4 cm) core prepared in example 1, and the experimental procedure was repeated for the steps of preparing the experiment, establishing the original formation conditions, water invasion by formation water failure, and calculation of recovery ratio in example 1, and specific data were obtained as shown in table 2.
TABLE 2 data of core water invasion simulation experiments of semi-permeable interlayers (4 cm)
The semi-permeable interlayer (4 cm) core water invasion simulation experiment data are drawn to be a graph, as shown in fig. 5, in the early stage of the failure process, the cumulative recovery rate rapidly rises, because the interlayer is in the middle, water body firstly invades the bottom reservoir layer and then is blocked by the interlayer and then invades the upper reservoir layer, so that the unit pressure drop gas production rate firstly rises and then falls and then rises until the core water is at 25MPa, the cumulative recovery rate slowly rises, and the unit pressure drop gas production rate slowly continues to fall after suddenly falling due to the fact that the water enters the gas-water co-recovery stage after water is taken in.
Referring to the same calculation method of example 1, R was calculated w (％)、f w (％)：
Wherein V is the cumulative gas volume, V gs Is the volume of natural gas at ground conditions.
W is the accumulated water yield, V ws Is the volume of formation water under the ground condition, and ρ is the formation water density.
Therefore, the final cumulative recovery ratio was 84.49%, and the final water content f was 18.42%.
Example 3
Experiments were performed using the semi-closed interlayer (2 cm) core prepared in example 1, and the experimental procedure was repeated for the steps of preparing the experiment, establishing the original formation conditions, water invasion by formation water failure, and calculation of recovery ratio in example 1, and specific data were obtained as shown in table 3.
TABLE 3 data of core water invasion simulation experiments for semi-closed interlayer (2 cm)
The core water invasion simulation experimental data of a semi-closed interlayer (2 cm) are drawn to be a graph, as shown in fig. 6, in the early stage of the failure process, the cumulative recovery rate rapidly rises, because the interlayer is in the middle, water body firstly invades a bottom reservoir layer and then is blocked by the interlayer and then invades an upper reservoir layer, so that the gas yield per unit pressure drop firstly rises and then falls and then rises until the core water meets 25MPa, the cumulative recovery rate slowly rises, and the gas yield per unit pressure drop slowly continues to fall after suddenly falling because the water enters a gas-water co-recovery stage after meeting water.
Referring to the same calculation method of example 1, R was calculated w (％)、d w (％)：
Wherein V is the cumulative gas volume, V gs Is the volume of natural gas at ground conditions.
W is the cumulative yieldWater quantity, V ws Is the volume of formation water under the ground condition, and ρ is the formation water density.
Therefore, the final cumulative recovery ratio was 79.59%, and the final water content f was 22.53%.
The experimental results of the embodiment 1, the embodiment 2 and the embodiment 3 are compared with the interlayer, the influence on the water invasion of the gas reservoir is obvious, the thicker the interlayer is, the better the interlayer is sealed, the water invasion blocking effect of the stratum is better, the lower the water pressure is, the longer the anhydrous acquisition period is provided, the higher the final recovery ratio is, and the lower the water content is.
The invention realizes the high-temperature high-pressure water invasion experimental method of the gas reservoir considering different gas-water distribution modes, can realize the simulation of various different pressure and water invasion scenes, has adjustable confining pressure and controllable natural gas injection process and selectable environment temperature, and can simulate the influence of the gas reservoir with different gas-water distribution modes of the interlayer on the water invasion of the gas reservoir. The environmental conditions are adjustable and controllable, so that the accurate control of different stratum pressures and different stratum temperatures under the change of different stratum and interlayer types can be realized, and the accuracy of the complex-scene gas reservoir development and research can be better improved.
Claims (10)
1. The gas reservoir water invasion experimental method with different gas-water distribution modes is characterized by comprising the following steps of:
s1, preparing a rock core: taking carbonate rock, manually making a joint, then drilling a core, and ensuring that the drilled core passes through a manual joint making structure;
extracting and engraving the interlayer to manufacture an engraving model picture;
carving the interlayer according to the carving model diagram;
s2, installing a rock core: placing the interlayer between the split two halves of the core, and then placing the interlayer into a core holder;
s3, stratum pressure environment debugging: applying confining pressure to the core holder to enable the confining pressure to reach P 0 ；
Injecting inert gas to displace air in the system; injecting natural gas, displacing the injected inert gas in the core holder until the natural gas escapes from the separator, and measuring the gas composition;
the inlet end and the outlet end of the core holder are exchanged, natural gas is injected, and the rest inert gas in the core holder is displaced until only the natural gas escapes from the separator;
s4, stratum water failure water invasion: controlling the confining pressure to be stabilized at P 0 The formation water is processed according to the formation pressure P i Injecting the core holder from the inlet end, and realizing pressure P through regulating the back pressure valve i Down to P 3 Separating gas and water by a separator, and measuring the cumulative gas volume V i And accumulated water yield W i The method comprises the steps of carrying out a first treatment on the surface of the Recording water outlet time until the outlet end produces water completely;
s5, calculating recovery ratio: calculating recovery ratio R of constant-pressure stratum water invasion stage w Determining the density of formation water as rho, and calculating the water content ƒ of the constant-pressure formation water invasion stage w ；
Wherein, the rock core holder is arranged in a constant temperature oven.
2. The method according to claim 1, wherein in step S1, a block-shaped carbonate rock sample is taken, an artificial natural single slit is formed, a cylindrical full-diameter core is drilled by a drill, and cleaning and drying treatment is performed.
3. The method for gas reservoir water invasion experiments according to different gas-water distribution modes according to claim 1, wherein in step S1, the volume V, the porosity Φ, and the absolute permeability of the core are measured, and the core pore volume is calculatedV p 。
4. A gas reservoir water invasion assay according to different gas water distribution modes according to claim 1, wherein in step S1, the formation water volume V is prepared ws ：
V ws =V p /B w
wherein ,V p pore volume of core, B w Is the volume coefficient of formation water under the current formation pressure, B w =1.02~1.03。
5. A gas reservoir water invasion assay according to different gas water distribution modes according to claim 1, wherein in step S1, the volume V of natural gas under surface conditions is prepared gs ：
V gs =V p /B gi
Wherein Vp is the core pore volume, B gi Is the volumetric coefficient of natural gas at the original formation pressure.
6. The gas reservoir water invasion assay method according to different gas water distribution modes according to claim 1, wherein in step S2, the artificially prepared full diameter core is split in half in the axial direction, then the spacer layer is placed between the split two half full diameter cores, the core and the spacer layer are fixed by tape winding, and the two half full diameter cores and the spacer layer are integrally placed in the holder.
7. The method according to claim 1, wherein in step S3, the inlet end of the core holder is connected to the inert gas storage container, the natural gas storage container and the formation water storage container in parallel, and the inert gas, the natural gas or the formation water in the storage containers are independently or together driven into the core holder by the driving device.
8. A gas reservoir water invasion assay according to different gas water distribution modes according to claim 1, wherein the inert gas storage vessel, natural gas storage vessel and formation water storage vessel are placed in a thermostatted oven.
9. The gas reservoir water invasion assay method of different gas-water distribution modes according to claim 1, wherein in step S3, an outlet end of the core holder is connected to a back pressure valve, and the back pressure valve is connected to a back pressure pump and a separation pipeline;
the separation pipeline comprises a separator, a gas meter and a chromatograph which are connected in sequence.
10. The method for gas reservoir water invasion experiments in different gas water distribution modes according to claim 1, wherein the pressure gas production volume V in each stage is measured by a gas meter i And water production volume W i ；
In step S5, calculating the recovery ratio R of the constant pressure stratum water invasion stage w ：
R w =Vi/V gs
R w Is the recovery ratio of constant pressure stratum water invasion stage, V gs Is the volume of natural gas under the ground condition, V i Is the gas production volume;
in step S5, the water content ƒ of the constant-pressure stratum water invasion stage is calculated w ：
ƒ w =Wi/（V ws ·ρ）
ƒ w Is the water content of the constant-pressure stratum water invasion stage, W i To produce water volume, V ws Is the volume of formation water under surface conditions,ρis the formation water density.
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