Synergistic Modes and Enhanced Oil Recovery Mechanism of CO 2 Synergistic Huff and Puff

: With the gradual declining of oil increment performance of CO 2 huff-and-puff wells, the overall oil exchange rate shows a downward tendency. In this regard, CO 2 synergistic huff-and-puff technologies have been proposed to maintain the excellent effect and extend the technical life of such wells. However, there is no speciﬁc research on the mechanism and synergistic mode of CO 2 huff and puff in horizontal wells. This study aims to establish the synergistic mode and determine the adaptability and acting mechanism of CO 2 synergistic huff and puff. Three synergistic huff-and-puff modes are proposed based on the peculiarity of the fault-block reservoir’s small oil-bearing area and broken geological structure. We establish three typical CO 2 synergistic huff-and-puff models and analyze the inﬂuence of different geological and development factors on the huff-and-puff performance with numerical simulation. Each factor’s sensitivity is clariﬁed, and the enhanced oil recovery (EOR) mechanism of CO 2 synergistic huff and puff is proposed. The sensitivity evaluation results show that the reservoir rhythm, inter-well passage, well spacing, high-position well liquid production rate, and middle-well liquid production rate are extremely sensitive factors; the stratum dip and injection volume allocation scheme are sensitive factors; and the relationship with structural isobaths is insensitive. The EOR mechanism of synergistic huff and puff includes gravity differentiation, supplementary formation energy, CO 2 forming foam ﬂooding, and coupling effect of production rate and oil reservoirs. The implementation conditions of the two-well cooperative stimulation mode are the simplest. The two-well model is suitable for thick oil layers with a positive rhythm and large formation dip. The single-well mode requires no channeling between the wells, and the multi-well mode requires multi-well rows and can control the intermediate well’s ﬂuid production rate. Field application at C2X1 block shows a good performance with a total oil increment of 1280 t and an average water-cut reduction of 57.7%. period, indicating that bottom water cresting occurs. The closer to the edge and bottom water, the more evident the edge and bottom water intrusion. Comprehensive analysis results of well performance of these two types of wells in different sedimentary rhythms indicate that the performance of synergistic CO 2 huff and puff is considerably affected by the sedimentary rhythm. contrast, the the water cur reduction


Introduction
In recent years, the greenhouse effect has become one of the 10 major environmental problems that threaten human survival, and it has become a focus of attention. Although excessive CO 2 content is an essential factor leading to climate change and even severe natural disasters, it is useful in oilfield development [1]. Reasonable use of CO 2 can effectively increase oilfield production and alleviate energy shortage [2][3][4]. The CO 2 flooding and storage technology uses CO 2 to drive oil to improve oil recovery while realizing the geological storage of CO 2 . Such technology provides economic and social benefits and is also the most effective manner to reduce greenhouse gas emissions under current economic and technical conditions. The CO 2 storages are mainly divided into geological storage, marine storage, and vegetation [5]. There are three types of burial, However, there is no specific research on the enhanced oil recovery (EOR) mecha nism and synergistic mode of CO2 synergistic huff and puff in horizontal wells. Based o fault-block reservoirs' characteristics with small oil-bearing area, broken structure, an lack of well-developed well patterns, three synergistic huff-and-puff modes are proposed Through numerical simulation, we study the influence of geological and developmen factors on CO2 synergistic huff-and-puff performance. Based on the variation of oil incre ment, water cut, water saturation distribution, and oil viscosity distribution, each factor sensitivity is clarified. The EOR mechanism and adaptability of synergistic modes ar summarized. A field application of CO2 synergistic huff and puff is performed to verif the applicability and development performance of CO2 synergistic huff and puff.

Numerical Simulation Model
There are many geological and development factors that need to be considered [33 35]. On the one hand, the physical simulation experiment is time consuming, and ther are many uncontrollable factors during the experiment. On the other hand, the numerica model is highly controllable, and a factor analysis can be reliably performed. Therefor numerical simulation methods are used to establish a typical model based on the targe block reservoir parameters to study the influence of geological and development factor on the throughput effect under different throughput modes.

Model Design
An eclipse digital simulation software and component modules were used to estab lish a typical model of synergistic CO2 huff and puff. The simulation area is 350 m lon and 200 m wide, and the model uses horizontal well production. The third layer is pro duced by default; that is, the horizontal section of the horizontal well is located one thir away from the top of the oil layer. The grid size of the area near the horizontal well is 5 m × 5 m, whereas the grid of other areas is 10 m × 10 m. A total of 11 grids are divided in th Z direction, and the total grid number of the typical model after encryption is 17,600. Th model parameters are set according to the reservoir parameters of the C2X1 block. Th model porosity is 0.26; the permeability increases with the depth from 30 to 800 mD t simulate a positive rhythm reservoir; the initial average oil saturation is 0.55, which de creases with the increase in the structural depth; the initial formation pressure is 17.7 MP and the crude oil viscosity at formation temperature is 50 mPa.s. Two typical models ar designed, one with two production wells (model I) and the other with three productio wells (model II), to study the geological parameters and development parameter chang laws under different synergistic huff-and-puff modes. P1 and P2 in model I are located i the low and high parts of the structure, respectively. In model II, P1 is located in the low However, there is no specific research on the enhanced oil recovery (EOR) mechanism and synergistic mode of CO 2 synergistic huff and puff in horizontal wells. Based on faultblock reservoirs' characteristics with small oil-bearing area, broken structure, and lack of well-developed well patterns, three synergistic huff-and-puff modes are proposed. Through numerical simulation, we study the influence of geological and development factors on CO 2 synergistic huff-and-puff performance. Based on the variation of oil increment, water cut, water saturation distribution, and oil viscosity distribution, each factor's sensitivity is clarified. The EOR mechanism and adaptability of synergistic modes are summarized. A field application of CO 2 synergistic huff and puff is performed to verify the applicability and development performance of CO 2 synergistic huff and puff.

Numerical Simulation Model
There are many geological and development factors that need to be considered [33][34][35]. On the one hand, the physical simulation experiment is time consuming, and there are many uncontrollable factors during the experiment. On the other hand, the numerical model is highly controllable, and a factor analysis can be reliably performed. Therefore, numerical simulation methods are used to establish a typical model based on the target block reservoir parameters to study the influence of geological and development factors on the throughput effect under different throughput modes.

Model Design
An eclipse digital simulation software and component modules were used to establish a typical model of synergistic CO 2 huff and puff. The simulation area is 350 m long and 200 m wide, and the model uses horizontal well production. The third layer is produced by default; that is, the horizontal section of the horizontal well is located one third away from the top of the oil layer. The grid size of the area near the horizontal well is 5 m × 5 m, whereas the grid of other areas is 10 m × 10 m. A total of 11 grids are divided in the Z direction, and the total grid number of the typical model after encryption is 17,600. The model parameters are set according to the reservoir parameters of the C2X1 block. The model porosity is 0.26; the permeability increases with the depth from 30 to 800 mD to simulate a positive rhythm reservoir; the initial average oil saturation is 0.55, which decreases with the increase in the structural depth; the initial formation pressure is 17.7 MPa; and the crude oil viscosity at formation temperature is 50 mPa·s. Two typical models are designed, one with two production wells (model I) and the other with three production wells (model II), to study the geological parameters and development parameter change laws under different synergistic huff-and-puff modes. P1 and P2 in model I are located in the low and high parts of the structure, respectively. In model II, P1 is located in the low part, P2 is located in the middle, and P3 is located in the high part of the structure. The two ies 2021, 14, x FOR PEER REVIEW two models share the same gridding partition, fluid properties, a tics. Similarly, the oil saturation distribution of each model is sho

CO2-Oil System Phase Behavior
In order to calculate the CO2 concentration accurately in the puff, the components of production well output content were a system phase behavior matching [36], and the output content com Table 1. The dissolution and molecular diffusion [37] of CO2 in cr ing, oil viscosity reduction, and gravity number changing [38]. crucial for enhancing oil recovery in the process of CO2 synerg Therefore, the viscosity and density of the CO2-oil system with d tions were tested to present the properties of CO2 and oil in the s Table 2 show the viscosity and density of CO2-oil system, and it ies 2021, 14, x FOR PEER REVIEW two models share the same gridding partition, fluid properties, a tics. Similarly, the oil saturation distribution of each model is sho

CO2-Oil System Phase Behavior
In order to calculate the CO2 concentration accurately in the puff, the components of production well output content were a system phase behavior matching [36], and the output content com Table 1. The dissolution and molecular diffusion [37] of CO2 in cr ing, oil viscosity reduction, and gravity number changing [38]. crucial for enhancing oil recovery in the process of CO2 synerg Therefore, the viscosity and density of the CO2-oil system with d tions were tested to present the properties of CO2 and oil in the s Table 2 show the viscosity and density of CO2-oil system, and it cosity and density decrease with the increase in CO2 concentratio

CO 2 -Oil System Phase Behavior
In order to calculate the CO 2 concentration accurately in the process of CO 2 huff and puff, the components of production well output content were analyzed to conduct the system phase behavior matching [36], and the output content composition was shown in Table 1. The dissolution and molecular diffusion [37] of CO 2 in crude oil lead to oil swelling, oil viscosity reduction, and gravity number changing [38]. CO 2 -oil mixing effect is crucial for enhancing oil recovery in the process of CO 2 synergistic huff and puff [39]. Therefore, the viscosity and density of the CO 2 -oil system with different CO 2 concentrations were tested to present the properties of CO 2 and oil in the simulation. Figure 4 and Table 2 show the viscosity and density of CO 2 -oil system, and it can be seen that the viscosity and density decrease with the increase in CO 2 concentration. The critical properties of CO 2 -oil system including bubble point pressure, critical pressure, and critical temperature are 5.94 MPa, 2.27 MPa, and 785.02 • C, respectively.

Basic Simulation Parameters
In the research process, in addition to the target parameters of the study, the parameters of the model are the stratum dip angle of 6°, oil layer thickness of 6.6 a large body of water with sufficient energy. The reservoir has positive rhythm, L coefficient of 0.5, and crude oil viscosity at formation temperature is 50 mPa.s. Th zontal section length is 70 m, parallel to the oil layer, and the entire horizontal se perforated to the production oil. There is no interlayer, the horizontal section is loc the middle and upper parts of the oil layer, and the horizontal well is directly op Then, we perform CO2 huff and puff when the water cut of production well reach The daily gas injection rate of a single well is 100 t with the total injection volume o In sequence, the gas injection well is shut down for 30 days. After well soaking, P1 switch to open simultaneously. The basic parameters of the typical model are sh Table 3. Table 3. Basic parameters of the typical numerical simulation model.

Serial Number
Factor Parameter Level 1 Stratum dip (°) 6 2 Effective thickness of oil layer (m) 6.6 3 Energy Sufficient water on the sides and botto 4 Sedimentary rhythm Positive rhythm

Basic Simulation Parameters
In the research process, in addition to the target parameters of the study, the default parameters of the model are the stratum dip angle of 6 • , oil layer thickness of 6.6 m, and a large body of water with sufficient energy. The reservoir has positive rhythm, Lorentz coefficient of 0.5, and crude oil viscosity at formation temperature is 50 mPa·s. The horizontal section length is 70 m, parallel to the oil layer, and the entire horizontal section is perforated to the production oil. There is no interlayer, the horizontal section is located in the middle and upper parts of the oil layer, and the horizontal well is directly opposite. Then, we perform CO 2 huff and puff when the water cut of production well reaches 98%. The daily gas injection rate of a single well is 100 t with the total injection volume of 400 t. In sequence, the gas injection well is shut down for 30 days. After well soaking, P1 and P2 switch to open simultaneously. The basic parameters of the typical model are shown in Table 3. Table 3. Basic parameters of the typical numerical simulation model.

Serial Number
Factor Parameter Level Effective thickness of oil layer (m) 6. 6 3 Energy Sufficient water on the sides and bottom 4 Sedimentary rhythm Positive rhythm 5 Heterogeneity (Lorentz coefficient) 0.5 6 Crude oil viscosity (mPa·s) 50 7 Interlayer No compartment 8 Horizontal section length (m) 70 9 Well spacing (m) 40 10 Injection volume (t) 400 11 Well stuffy time (d) 30 12 Actual length of liquid production Entire horizontal section

Research Methodology
This paper aims to propose the particular mechanism of enhanced oil recovery and the applicable conditions of the synergistic mode of CO 2 synergistic huff and puff in fault-block reservoirs.
According to the feature of fault-block reservoir, we design three synergistic modes to conduct quantitative study of the influence of the geological and development factors to oil increment and water cut. Furthermore, the quantitative research results were used to determine the main control factors through sensitivity analysis based on the indicator parameter of sensitivity degree.
Then, making use of the sensitivity research results, from two aspects of reservoir conditions and development conditions, the qualitative and partial quantitative applicable situations of different synergistic modes were proposed to guide the implementation of CO 2 huff and puff.
Besides ordinary enhanced oil recovery mechanism of CO 2 , there must be other mechanisms to strengthen the enhanced oil recovery efficiency for CO 2 synergistic huff and puff. By analyzing the distribution of CO 2 , residual oil and water in the process of CO 2 synergistic huff and puff at different levels of geological and development factors, the particular enhance oil recovery mechanisms were summarized.

Synergistic Mode
Fault-block reservoirs have small oil-bearing areas and fractured structures, which hinder the establishment of a completed injection-production well pattern [11,17]. The inclination angle of the fault-block reservoir controlled by the structure is the key factor that affects the development performance. In addition, the development performances of wells in different structural positions of the fault-block reservoir are different. Several CO 2 huff-and-puff field practices at home and abroad, comprehensive analysis results of implementation plans, and development effects of CO 2 huff-and-puff field applications in heavy oil and fault-block reservoirs have indicated that wells in the lower structural position show better performance in CO 2 huff and puff. Moreover, for the fault-block reservoir, the limitation of horizontal well arrangement along the direction of structural rise is identified as three rows [40,41]. We have calculated the development conditions of the CO 2 synergistic huff-and-puff well group, which include the number of synergistic huffand-puff wells, structural position of synergistic wells, positional relationship between the synergistic wells' ligature and structural contour, synergistic well spacing, CO 2 injection volume, and type of well pattern. Based on statistical data, the synergistic modes are summarized. According to the number of huff-and-puff wells, the implementation modes can be divided into three categories: single-well, two-well, and multi-well synergistic modes. Based on these three types, the distribution of oil, gas, and water movement before and after the stimulation treatment were evaluated. The synergistic modes are shown in Table 4. Table 4. Synergistic mode of CO 2 huff and puff.

Mode Type Synergistic Mode
Two-well synergistic mode Two production wells with simultaneous injection of gas Single-well synergistic mode Two production wells, gas injected into low-position wells Multi-well synergistic mode Three production wells, gas injected into lower-and higher-structural-position wells

Simulation Scheme
By means of reservoir numerical simulation, the geological and development factors that have a higher impact on oil increase and water-cut reduction are selected. The geological factors are objective and internal principal contradictions, whereas the development factors are subjective and external secondary contradictions. The structural conditions of geological factors, heterogeneity of the reservoir, and liquid production rate of development factors are the key aspects that affect the performance of CO 2 synergistic stimulation development. By considering the value levels of different factors, the influence law of each factor on the synergistic huff-and-puff performance is studied to provide a reference for the reservoir adaptability study of horizontal well CO 2 synergistic huff and puff.
(1) Two-well synergistic mode When two horizontal wells perform CO 2 synergistic huff and puff, geological factors, such as stratum dip, sedimentary rhythm, and permeability contrast of inter-well channel, need to be considered. It is necessary to study the allocation of CO 2 injection volume between high-and low-structural-position wells, the well spacing, and the relationship with the depth isobaths. The parameter values of each factor are designed based on the parameter range of fault-block reservoirs. Geological and development factors and the parameter level of each factor of the two-well synergistic mode are shown in Table 5. (2) Single-well synergistic mode Single-well synergistic huff and puff means that when two rows of horizontal wells are used in reservoir development, CO 2 huff and puff is implemented in lower position horizontal wells, while normal production is maintained in higher position horizontal wells. Compared with the two-well synergistic huff-and-puff mode, the research factors including injection volume allocation and the relationship with structural isobaths are uninvolved. Moreover, the influence law of stratum dip and sedimentary rhythm on production performance is universal. Under this mode, it is necessary to study the effect of permeability contrast of inter-well channel, well spacing, and liquid production rate of high-structural-position wells on the performance of CO 2 synergistic huff and puff. The factors and parameter levels of the single-well synergistic mode are shown in Table 6. (3) Multi-well synergistic mode Multi-well synergistic huff and puff means that when there are three rows of horizontal production wells, and CO 2 huff and puff is performed in high-and low-position wells, while the middle-position well is normally opened for production. This mode is clearly different from the previous two modes, particularly the liquid production rate of the middle well. Factors and parameter levels are shown in Table 7.

Two-Well Synergistic Mode
For this mode, the following conditions are applied: stratum dip of 6 • , thickness of the oil layer of 6.6 m, a large body of water with sufficient energy, positive rhythm, Lorentz coefficient of 0.5, length of the horizontal section of 70 m parallel to the oil layer, entire section discharged, viscosity of the crude oil of 90 mPa·s, no interlayers, and horizontal section located in the middle-upper part of the oil layer. The two horizontal wells are facing each other: P1 is in the lower position, and P2 is in the higher position. After the water cut of P1 reaches 98%, P1 and P2 simultaneously perform CO 2 huff and puff. The daily gas injection volume of the well is 100 t, a total of 400 t is injected, and the wells are closed for 30 days. After well stuffy, P1 and P2 are opened for simultaneous production. During the simulation process, the model parameter settings are modified according to the parameter value.
(1) Stratum dip The stratum dip has a non-negligible effect on the water flooding development. When the local dip exists, the performance of the production wells in different structural positions is different [42]. In low structural positions, the water cut of the production wells rises faster, whereas water breakthrough occurs later for production wells in high structural positions. To analyze the influence of the stratum dip on the synergistic CO 2 huff-and-puff development performance, we set the stratum dip to 3, 6, and 15 • in the typical model. Figure 5 shows the oil increment and water-cut reduction of P1, P2, and well groups during the validity period. From Figure 5, it is observed that as the stratum dip increases, the oil increment of low-position production wells decreases, whereas it increases for high-position production wells. After the stratum dip angle exceeds 6 • , the oil increment and water cut of the well group change slightly. They show a tendency of first increasing and then stabilizing with the increase in the stratum dip. Figure 6 shows the oil viscosity distribution after well stuffy. The figure indicates that when the stratum dip is 3 • , the viscosity of the crude oil near the production well decreases, but there is no significant change in the density of the crude oil between P1 and P2. When the stratum dip increases to 15 • , the range of oil viscosity reduction between wells continues to increase, indicating that under the action of gravity, the higher the stratum dip, the more evident the effect of gravity differentiation, which expands the action range of CO 2 . Hence, the stratum dip is a favorable factor for synergistic CO 2 huff and puff. Figure 6 shows the distribution of oil saturation after the validity period. In Figure 7, we can see that as the stratum dip increases, the production range of P1 decreases because the injected gas moves upward under the action of gravity. As a result, the CO 2 that acts on the low structural part decreases, and the performance of well P1 becomes worse. For the high structural and inter-well parts, as the stratum dip increases, the production range becomes larger, and the performance of P2 gradually improves.
positions is different [42]. In low structural positions, the water cut of the produ rises faster, whereas water breakthrough occurs later for production wells in tural positions. To analyze the influence of the stratum dip on the synergisti and-puff development performance, we set the stratum dip to 3, 6, and 15° in model. Figure 5 shows the oil increment and water-cut reduction of P1, P2, and w during the validity period. From Figure 5, it is observed that as the stratum di the oil increment of low-position production wells decreases, whereas it in high-position production wells. After the stratum dip angle exceeds 6°, the oi and water cut of the well group change slightly. They show a tendency of firs and then stabilizing with the increase in the stratum dip. Figure 6 shows the o distribution after well stuffy. The figure indicates that when the stratum dip is cosity of the crude oil near the production well decreases, but there is no change in the density of the crude oil between P1 and P2. When the stratum d to 15°, the range of oil viscosity reduction between wells continues to increase that under the action of gravity, the higher the stratum dip, the more evident t gravity differentiation, which expands the action range of CO2. Hence, the str a favorable factor for synergistic CO2 huff and puff. Figure 6 shows the distrib saturation after the validity period. In Figure 7, we can see that as the strat creases, the production range of P1 decreases because the injected gas moves u der the action of gravity. As a result, the CO2 that acts on the low structural par and the performance of well P1 becomes worse. For the high structural and parts, as the stratum dip increases, the production range becomes larger, and mance of P2 gradually improves.  The stratum dip has a non-negligible effect on the water flooding development. When the local dip exists, the performance of the production wells in different structural positions is different [42]. In low structural positions, the water cut of the production wells rises faster, whereas water breakthrough occurs later for production wells in high structural positions. To analyze the influence of the stratum dip on the synergistic CO2 huffand-puff development performance, we set the stratum dip to 3, 6, and 15° in the typical model. Figure 5 shows the oil increment and water-cut reduction of P1, P2, and well groups during the validity period. From Figure 5, it is observed that as the stratum dip increases, the oil increment of low-position production wells decreases, whereas it increases for high-position production wells. After the stratum dip angle exceeds 6°, the oil increment and water cut of the well group change slightly. They show a tendency of first increasing and then stabilizing with the increase in the stratum dip. Figure 6 shows the oil viscosity distribution after well stuffy. The figure indicates that when the stratum dip is 3°, the viscosity of the crude oil near the production well decreases, but there is no significant change in the density of the crude oil between P1 and P2. When the stratum dip increases to 15°, the range of oil viscosity reduction between wells continues to increase, indicating that under the action of gravity, the higher the stratum dip, the more evident the effect of gravity differentiation, which expands the action range of CO2. Hence, the stratum dip is a favorable factor for synergistic CO2 huff and puff. Figure 6 shows the distribution of oil saturation after the validity period. In Figure 7, we can see that as the stratum dip increases, the production range of P1 decreases because the injected gas moves upward under the action of gravity. As a result, the CO2 that acts on the low structural part decreases, and the performance of well P1 becomes worse. For the high structural and inter-well parts, as the stratum dip increases, the production range becomes larger, and the performance of P2 gradually improves.  (2) Sedimentary rhythm and well type The water flooding field application indicates that the sedimentary rhythm mode of the reservoir is closely related to reservoir development performance [43]. The physical properties and oil saturation of the lower part of positive rhythm oil layer are better than those of the upper part, and the utilization degree of the lower part is also higher. The main productive zone of reverse rhythm oil layer is located in the upper part. This means that the lower part does not produce oil; thus, the performance of water flooding development is poor. The longitudinal oil-water distribution of homogeneous oil layers is relatively uniform, and the development performance is the relation between positive-and negative-rhythm reservoirs. For fault-block oil reservoirs, edge and bottom water are common. The positive rhythm, homogeneous, and reverse rhythm models are established to study the influence of well types and different formation sedimentary rhythms on the performance of synergistic CO2 huff and puff when the production well is close to the edge and bottom water. In addition, horizontal and vertical wells are used for CO2 synergistic huff and puff.
The oil increment of horizontal well P1, vertical well P2, and well groups are shown in Figure 8. It can be seen from Figure 8 that the oil increment of P1 and P2 decreases with the changing of sedimentary rhythm. For the P1 well, the oil increment decreases from 586 t of positive rhythm and 566 t of homogeneous reservoir to 506 t of reverse rhythm. For the P2 well, the oil increment decreases from 675 t of positive rhythm and 549 t of homogeneous reservoir to 480 t of reverse rhythm. Comparing the oil increment of horizontal well P1 and vertical well P2, it was observed that the oil increasing performance of vertical wells in positive rhythm reservoirs is slightly better than that of horizontal wells. For homogeneous and reverse rhythm reservoirs, the development performance of horizontal wells is slightly better than that of vertical wells. The total oil increment of the well group is 1260 t for positive rhythm, 1115 t for the homogeneous oil reservoir, and 986 t for the reverse rhythm reservoir, and the total oil increment of the well group gradually decreases. Therefore, when the mixed well pattern of vertical and horizontal wells is implemented for synergistic CO2 huff and puff, positive rhythm is the optimal choice, followed by the homogeneous reservoir, and the reverse rhythm is the worst option. Figure 9 shows the oil viscosity distribution after well stuffy. Comparing the viscosity reduction range, we can conclude that crude oil viscosity reduction is the largest for the positive rhythm reservoir, followed by homogeneous and reverse rhythm reservoirs. In addition, the viscosity reduction range of the reverse rhythm reservoir is concentrated in the upper part of the reservoir, and the longitudinal sweep effect is poor. Figure 10 shows the oil saturation distribution after validity period. Comparing the oil saturation distribution of the three different sedimentary rhythms, it was found that the decreasing range of oil saturation in the positive rhythm reservoir is evidently large, that is, the range of reservoir utilization during the validity period is larger. The porosity and permeability of the lower part of the positive rhythm reservoir are relatively high. Under the action of CO2 injection, the crude oil expands, and the gravity differentiation is more effective. The positive rhythm reservoir shows better performance of synergistic CO2 huff and puff. The oil (2) Sedimentary rhythm and well type The water flooding field application indicates that the sedimentary rhythm mode of the reservoir is closely related to reservoir development performance [43]. The physical properties and oil saturation of the lower part of positive rhythm oil layer are better than those of the upper part, and the utilization degree of the lower part is also higher. The main productive zone of reverse rhythm oil layer is located in the upper part. This means that the lower part does not produce oil; thus, the performance of water flooding development is poor. The longitudinal oil-water distribution of homogeneous oil layers is relatively uniform, and the development performance is the relation between positive-and negativerhythm reservoirs. For fault-block oil reservoirs, edge and bottom water are common. The positive rhythm, homogeneous, and reverse rhythm models are established to study the influence of well types and different formation sedimentary rhythms on the performance of synergistic CO 2 huff and puff when the production well is close to the edge and bottom water. In addition, horizontal and vertical wells are used for CO 2 synergistic huff and puff.
The oil increment of horizontal well P1, vertical well P2, and well groups are shown in Figure 8. It can be seen from Figure 8 that the oil increment of P1 and P2 decreases with the changing of sedimentary rhythm. For the P1 well, the oil increment decreases from 586 t of positive rhythm and 566 t of homogeneous reservoir to 506 t of reverse rhythm. For the P2 well, the oil increment decreases from 675 t of positive rhythm and 549 t of homogeneous reservoir to 480 t of reverse rhythm. Comparing the oil increment of horizontal well P1 and vertical well P2, it was observed that the oil increasing performance of vertical wells in positive rhythm reservoirs is slightly better than that of horizontal wells. For homogeneous and reverse rhythm reservoirs, the development performance of horizontal wells is slightly better than that of vertical wells. The total oil increment of the well group is 1260 t for positive rhythm, 1115 t for the homogeneous oil reservoir, and 986 t for the reverse rhythm reservoir, and the total oil increment of the well group gradually decreases. Therefore, when the mixed well pattern of vertical and horizontal wells is implemented for synergistic CO 2 huff and puff, positive rhythm is the optimal choice, followed by the homogeneous reservoir, and the reverse rhythm is the worst option. Figure 9 shows the oil viscosity distribution after well stuffy. Comparing the viscosity reduction range, we can conclude that crude oil viscosity reduction is the largest for the positive rhythm reservoir, followed by homogeneous and reverse rhythm reservoirs. In addition, the viscosity reduction range of the reverse rhythm reservoir is concentrated in the upper part of the reservoir, and the longitudinal sweep effect is poor. Figure 10 shows the oil saturation distribution after validity period. Comparing the oil saturation distribution of the three different sedimentary rhythms, it was found that the decreasing range of oil saturation in the positive rhythm reservoir is evidently large, that is, the range of reservoir utilization during the validity period is larger. The porosity and permeability of the lower part of the positive rhythm reservoir are relatively high. Under the action of CO 2 injection, the crude oil expands, and the gravity differentiation is more effective. The positive rhythm reservoir shows better performance of synergistic CO 2 huff and puff. The oil saturation of the lower part of positive rhythm reservoir is lower after validity period, indicating that bottom water cresting occurs. The closer to the edge and bottom water, the more evident the edge and bottom water intrusion. Comprehensive analysis results of well performance of these two types of wells in different sedimentary rhythms indicate that the performance of synergistic CO 2 huff and puff is considerably affected by the sedimentary rhythm.
rgies 2021, 14, x FOR PEER REVIEW saturation of the lower part of positive rhythm reservoir is lower af indicating that bottom water cresting occurs. The closer to the edge an more evident the edge and bottom water intrusion. Comprehensive well performance of these two types of wells in different sedimentar that the performance of synergistic CO2 huff and puff is considerably imentary rhythm.   (3) Permeability contrast of inter-well channel The dominant flow channels between wells are considerably im uting the remaining oil during water flooding development [44]. For opment, existing studies have shown that the existence of dominant fl gas channeling along the flow channel and worsens the development flooding. To clarify the influence of the advantageous flow channels be performance of synergistic CO2 huff and puff, we set advantages flo simulation layers. The channel permeability contrasts are 1, 20, 50, an   (3) Permeability contrast of inter-well channel The dominant flow channels between wells are considerably important in distributing the remaining oil during water flooding development [44]. For gas flooding development, existing studies have shown that the existence of dominant flow channels causes gas channeling along the flow channel and worsens the development performance of gas flooding. To clarify the influence of the advantageous flow channels between wells on the performance of synergistic CO2 huff and puff, we set advantages flow channel in 3-11 simulation layers. The channel permeability contrasts are 1, 20, 50, and 100, and the permeability profiles diagrams of permeability contrast 1 and 100 are shown in Figure 11.  (3) Permeability contrast of inter-well channel The dominant flow channels between wells are considerably important in distributing the remaining oil during water flooding development [44]. For gas flooding development, existing studies have shown that the existence of dominant flow channels causes gas channeling along the flow channel and worsens the development performance of gas flooding. To clarify the influence of the advantageous flow channels between wells on the performance of synergistic CO2 huff and puff, we set advantages flow channel in 3-11 simulation layers. The channel permeability contrasts are 1, 20, 50, and 100, and the permeability profiles diagrams of permeability contrast 1 and 100 are shown in Figure 11. (3) Permeability contrast of inter-well channel The dominant flow channels between wells are considerably important in distributing the remaining oil during water flooding development [44]. For gas flooding development, existing studies have shown that the existence of dominant flow channels causes gas channeling along the flow channel and worsens the development performance of gas flooding. To clarify the influence of the advantageous flow channels between wells on the performance of synergistic CO 2 huff and puff, we set advantages flow channel in 3-11 simulation layers. The channel permeability contrasts are 1, 20, 50, and 100, and the permeability profiles diagrams of permeability contrast 1 and 100 are shown in Figure 11. The oil increment of P1, P2, and well group under different channel permeability contrasts is shown in Figure 12. The oil increment of well P1 increases with the increase in permeability contrast, whereas it decreases for well P2 as the channel permeability level difference increases. When the channel permeability contrast is 1, the oil increment of P1 well is 445 t, which is less than 628 t of P2. As the channel permeability contrast increases to 20, the oil increment of P1 increases to 657 t, but the oil increment of P2 decreases to 254 t. Subsequently, with the further increase in permeability contrast, the oil increment of both production wells decreases slightly. When there is no main flow channel, the highposition well presents a higher oil increment. Figure 13 shows the production gas-oil ratio (GOR) curve of P2. As the channel permeability contrast increases from 1 to 100, the GOR rises from 1600 to 15,000 m 3 /m 3 . The larger the channel permeability contrast, the more CO2 is consumed in the strong water washing layer, and the worse the well group oil increases.
Comparing the oil saturation before and after gas injection, shown in Figures 14 and  15, respectively, it was found that without channel, the oil saturation between production wells and near P1 increases. When the channel permeability contrast exceeds 1, the oil saturation between production wells decreases, and crude oil migrates down the channel. Therefore, in the presence of channels, CO2 is transported to the upper part of the oil layer under the influence of gravity differentiation, and crude oil migrates and accumulates to the lower part, resulting in a high oil increment of low-structural-position wells.  The oil increment of P1, P2, and well group under different channel permeability contrasts is shown in Figure 12. The oil increment of well P1 increases with the increase in permeability contrast, whereas it decreases for well P2 as the channel permeability level difference increases. When the channel permeability contrast is 1, the oil increment of P1 well is 445 t, which is less than 628 t of P2. As the channel permeability contrast increases to 20, the oil increment of P1 increases to 657 t, but the oil increment of P2 decreases to 254 t. Subsequently, with the further increase in permeability contrast, the oil increment of both production wells decreases slightly. When there is no main flow channel, the high-position well presents a higher oil increment. Figure 13 shows the production gas-oil ratio (GOR) curve of P2. As the channel permeability contrast increases from 1 to 100, the GOR rises from 1600 to 15,000 m 3 /m 3 . The larger the channel permeability contrast, the more CO 2 is consumed in the strong water washing layer, and the worse the well group oil increases.
The oil increment of P1, P2, and well group under different channel p contrasts is shown in Figure 12. The oil increment of well P1 increases with t in permeability contrast, whereas it decreases for well P2 as the channel perme difference increases. When the channel permeability contrast is 1, the oil incre well is 445 t, which is less than 628 t of P2. As the channel permeability contra to 20, the oil increment of P1 increases to 657 t, but the oil increment of P2 decr t. Subsequently, with the further increase in permeability contrast, the oil in both production wells decreases slightly. When there is no main flow channe position well presents a higher oil increment. Figure 13 shows the production g (GOR) curve of P2. As the channel permeability contrast increases from 1 to 10 rises from 1600 to 15,000 m 3 /m 3 . The larger the channel permeability contras CO2 is consumed in the strong water washing layer, and the worse the wel increases.
Comparing the oil saturation before and after gas injection, shown in Fig  15, respectively, it was found that without channel, the oil saturation between wells and near P1 increases. When the channel permeability contrast exceed saturation between production wells decreases, and crude oil migrates down t Therefore, in the presence of channels, CO2 is transported to the upper part of t under the influence of gravity differentiation, and crude oil migrates and accu the lower part, resulting in a high oil increment of low-structural-position wel   The oil increment of P1, P2, and well group under different channel p contrasts is shown in Figure 12. The oil increment of well P1 increases with t in permeability contrast, whereas it decreases for well P2 as the channel perme difference increases. When the channel permeability contrast is 1, the oil incre well is 445 t, which is less than 628 t of P2. As the channel permeability contra to 20, the oil increment of P1 increases to 657 t, but the oil increment of P2 decr t. Subsequently, with the further increase in permeability contrast, the oil in both production wells decreases slightly. When there is no main flow channe position well presents a higher oil increment. Figure 13 shows the production g (GOR) curve of P2. As the channel permeability contrast increases from 1 to 10 rises from 1600 to 15,000 m 3 /m 3 . The larger the channel permeability contras CO2 is consumed in the strong water washing layer, and the worse the we increases.
Comparing the oil saturation before and after gas injection, shown in Fig  15, respectively, it was found that without channel, the oil saturation between wells and near P1 increases. When the channel permeability contrast exceed saturation between production wells decreases, and crude oil migrates down t Therefore, in the presence of channels, CO2 is transported to the upper part of under the influence of gravity differentiation, and crude oil migrates and accu the lower part, resulting in a high oil increment of low-structural-position we  Comparing the oil saturation before and after gas injection, shown in Figures 14 and 15, respectively, it was found that without channel, the oil saturation between production wells and near P1 increases. When the channel permeability contrast exceeds 1, the oil saturation between production wells decreases, and crude oil migrates down the channel. Therefore, in the presence of channels, CO 2 is transported to the upper part of the oil layer under the influence of gravity differentiation, and crude oil migrates and accumulates to the lower part, resulting in a high oil increment of low-structural-position wells. (4) Allocation scheme of injection volume The total gas injection volume of the two wells is 800 t, which remains unchanged, and the injection volume allocation schemes are shown in Table 8.  Figure 16 shows the oil increment in each injection volume allocation scheme. As the injection volume of the low-structural-position well P1 increases from 100 to 700 t, the oil increment increases from 247 to 581 t, and the oil increment of the well group increases from 838 to 917 t. As the injection volume of P2 decreases, the oil increment decreases from 591 to 386 t. Although the oil increment of P2 gradually decreases, the synergistic CO2 huff and puff still shows a good performance because the oil increment of P1 is higher than the decrease in P2.
The viscosity distributions after well stuff of different injection volume allocation schemes are shown in Figure 17. According to Figure 17, as the injection volume of P1 (4) Allocation scheme of injection volume The total gas injection volume of the two wells is 800 t, which remains unchanged, and the injection volume allocation schemes are shown in Table 8.  Figure 16 shows the oil increment in each injection volume allocation scheme. As the injection volume of the low-structural-position well P1 increases from 100 to 700 t, the oil increment increases from 247 to 581 t, and the oil increment of the well group increases from 838 to 917 t. As the injection volume of P2 decreases, the oil increment decreases from 591 to 386 t. Although the oil increment of P2 gradually decreases, the synergistic CO2 huff and puff still shows a good performance because the oil increment of P1 is higher than the decrease in P2.
The viscosity distributions after well stuff of different injection volume allocation schemes are shown in Figure 17. According to Figure 17, as the injection volume of P1 (4) Allocation scheme of injection volume The total gas injection volume of the two wells is 800 t, which remains unchanged, and the injection volume allocation schemes are shown in Table 8.  Figure 16 shows the oil increment in each injection volume allocation scheme. As the injection volume of the low-structural-position well P1 increases from 100 to 700 t, the oil increment increases from 247 to 581 t, and the oil increment of the well group increases from 838 to 917 t. As the injection volume of P2 decreases, the oil increment decreases from 591 to 386 t. Although the oil increment of P2 gradually decreases, the synergistic CO 2 huff and puff still shows a good performance because the oil increment of P1 is higher than the decrease in P2.
water propulsion, the effect of CO2 to drive crude oil to a higher positi thus, the larger the injection amount at the lower-structural-position development performance of CO2 synergistic huff and puff.  The viscosity distributions after well stuff of different injection volume allocation schemes are shown in Figure 17. According to Figure 17, as the injection volume of P1 increases, the viscosity reduction range near the well P1 becomes larger, and the oil viscosity between P1 and P2 also decreases. Thus, the action range of CO 2 increases. Comparing the oil saturation of different injection schemes, shown in Figure 18, it was found that as the injection volume of the lower-structural-position well P1 increases, the average oil saturation decreases after validity period and the production degree and production action range increases. Under the influence of gravity differentiation and edge-bottom water propulsion, the effect of CO 2 to drive crude oil to a higher position is more evident; thus, the larger the injection amount at the lower-structural-position well, the better the development performance of CO 2 synergistic huff and puff. water propulsion, the effect of CO2 to drive crude oil to a higher position is more evident; thus, the larger the injection amount at the lower-structural-position well, the better the development performance of CO2 synergistic huff and puff.  (5) Well spacing Figure 19 shows the oil increment of P1, P2, and well group with different well spacing. It can be seen from the figure that as the well spacing increases, the oil increment of P1 increases, whereas it decreases for P2. The oil increment in the well group decreases and then increases, forming a V shape. When the well spacing is higher than 60 m, it has little influence on the performance of higher-structural-position wells.
The production water cut of P1 and P2 after well stuffy is shown in Figure 20. It can be seen from Figure 20 that as the well spacing increases, the lower-structural-position well P1 gradually decreases, whereas the water cut of P2 remains unchanged. Figure 21 shows the oil distribution after the production validity period, and the well spacing mainly affects the lower-structural-position well. The larger the well spacing, the higher the CO2 sweep volume, the lower the production water cut after well stuffy, and the higher the oil increment of the lower-structural-position well. If the well spacing exceeds 60 m, it has little effect on the performance of synergistic CO2 huff and puff of high-position wells.  (5) Well spacing Figure 19 shows the oil increment of P1, P2, and well group with different well spacing. It can be seen from the figure that as the well spacing increases, the oil increment of P1 increases, whereas it decreases for P2. The oil increment in the well group decreases and then increases, forming a V shape. When the well spacing is higher than 60 m, it has little influence on the performance of higher-structural-position wells. (5) Well spacing Figure 19 shows the oil increment of P1, P2, and well group with different ing. It can be seen from the figure that as the well spacing increases, the oil in P1 increases, whereas it decreases for P2. The oil increment in the well group and then increases, forming a V shape. When the well spacing is higher than 6 little influence on the performance of higher-structural-position wells.
The production water cut of P1 and P2 after well stuffy is shown in Figur be seen from Figure 20 that as the well spacing increases, the lower-structur well P1 gradually decreases, whereas the water cut of P2 remains unchanged shows the oil distribution after the production validity period, and the w mainly affects the lower-structural-position well. The larger the well spacing, the CO2 sweep volume, the lower the production water cut after well stuff higher the oil increment of the lower-structural-position well. If the well spaci 60 m, it has little effect on the performance of synergistic CO2 huff and puff of tion wells.  The production water cut of P1 and P2 after well stuffy is shown in Figure 20. It can be seen from Figure 20 that as the well spacing increases, the lower-structural-position well P1 gradually decreases, whereas the water cut of P2 remains unchanged. Figure 21 shows the oil distribution after the production validity period, and the well spacing mainly affects the lower-structural-position well. The larger the well spacing, the higher the CO 2 sweep volume, the lower the production water cut after well stuffy, and the higher the oil increment of the lower-structural-position well. If the well spacing exceeds 60 m, it has little effect on the performance of synergistic CO 2 huff and puff of high-position wells.   (6) Relationship with structural isobaths For horizontal wells, the relative direction of the horizontal section and the structural contours affect the performance of huff and puff [45]. To determine the influence of the relative direction of the horizontal section and structural isobaths on the development performance of synergistic CO2 huff and puff, a comparative study was made on the oil increment when the horizontal well line and the structural isobaths line are perpendicular and parallel. Figure 22 shows the oil increment of P1, P2, and well group of different relationships with structural isobaths. It was found that when the line of the huff-and-puff well is parallel to the isobaths, the oil increment is lower than that when the line is perpendicular to the isobaths. Thus, a better performance is obtained for the perpendicular case. This is because when the horizontal well is parallel to isobaths, it is affected by strong edge water, and water cut rapidly rises, which leads to a lower oil increment. The model parameters are consistent with the two-well synergistic mode. However, under the single-well synergistic mode, the high-position well P2 maintains production during the entire program of CO2 huff and puff of low-position well P1. Single-well synergistic CO2 huff and puff does not involve the allocation of injection volume and the re- (6) Relationship with structural isobaths For horizontal wells, the relative direction of the horizontal section and the structural contours affect the performance of huff and puff [45]. To determine the influence of the relative direction of the horizontal section and structural isobaths on the development performance of synergistic CO 2 huff and puff, a comparative study was made on the oil increment when the horizontal well line and the structural isobaths line are perpendicular and parallel. Figure 22 shows the oil increment of P1, P2, and well group of different relationships with structural isobaths. It was found that when the line of the huff-andpuff well is parallel to the isobaths, the oil increment is lower than that when the line is perpendicular to the isobaths. Thus, a better performance is obtained for the perpendicular case. This is because when the horizontal well is parallel to isobaths, it is affected by strong edge water, and water cut rapidly rises, which leads to a lower oil increment. (6) Relationship with structural isobaths For horizontal wells, the relative direction of the horizontal section and the structural contours affect the performance of huff and puff [45]. To determine the influence of the relative direction of the horizontal section and structural isobaths on the development performance of synergistic CO2 huff and puff, a comparative study was made on the oil increment when the horizontal well line and the structural isobaths line are perpendicular and parallel. Figure 22 shows the oil increment of P1, P2, and well group of different relationships with structural isobaths. It was found that when the line of the huff-and-puff well is parallel to the isobaths, the oil increment is lower than that when the line is perpendicular to the isobaths. Thus, a better performance is obtained for the perpendicular case. This is because when the horizontal well is parallel to isobaths, it is affected by strong edge water, and water cut rapidly rises, which leads to a lower oil increment. The model parameters are consistent with the two-well synergistic mode. However, under the single-well synergistic mode, the high-position well P2 maintains production during the entire program of CO2 huff and puff of low-position well P1. Single-well synergistic CO2 huff and puff does not involve the allocation of injection volume and the re-

Single-Well Synergistic Mode
The model parameters are consistent with the two-well synergistic mode. However, under the single-well synergistic mode, the high-position well P2 maintains production during the entire program of CO 2 huff and puff of low-position well P1. Single-well synergistic CO 2 huff and puff does not involve the allocation of injection volume and the relationship with isobaths. In addition, the influence of permeability contrast of interwell channel, stratum dip, and sedimentary rhythm on the development performance is generally applicable. Therefore, the main controlling factors in this mode are well spacing and daily liquid production rate of higher-structural-position wells.
(1) Permeability contrast of inter-well channel The dominant flow channels between wells are important in distributing the remaining oil during water flooding development. For gas flooding development, existing studies have shown that the existence of dominant flow channels causes gas channeling along the flow channel and worsen the development performance of gas flooding. The oil increment of P1, P2, and well group under different channel permeability contrasts is shown in Figure 23. The oil increment of well P1 increases with the increase in permeability contrast, and the oil increment of well P2 decreases as the channel permeability level difference increases. When the channel permeability contrast is 1, the oil increment of P1 well is 130 t, which is less than 1343 t of P2. As the channel permeability contrast increases to 20, the oil increment of P1 decreases to 85 t, and the oil increment of P2 decreases to 329 t. Subsequently, with further increase in permeability contrast, the oil increment of both production wells decreases slightly. When there is no main flow channel, the high-position well present a higher oil increment. Figure 24 shows the comparison of P1 water cut before and after CO 2 huff and puff. It can be seen that with the increase in permeability contrast of inter-well channel, the water cut after CO 2 huff and puff increases. This indicates that the higher the permeability contrast, the worse the water cur reduction ability.
Energies 2021, 14, x FOR PEER REVIEW in Figure 23. The oil increment of well P1 increases with the increase in permeabil trast, and the oil increment of well P2 decreases as the channel permeability leve ence increases. When the channel permeability contrast is 1, the oil increment of is 130 t, which is less than 1343 t of P2. As the channel permeability contrast incr 20, the oil increment of P1 decreases to 85 t, and the oil increment of P2 decreases Subsequently, with further increase in permeability contrast, the oil increment production wells decreases slightly. When there is no main flow channel, the hig tion well present a higher oil increment. Figure 24 shows the comparison of P1 w before and after CO2 huff and puff. It can be seen that with the increase in perm contrast of inter-well channel, the water cut after CO2 huff and puff increases. Th cates that the higher the permeability contrast, the worse the water cur reduction  (2) Well Spacing  Figure 23. The oil increment of well P1 increases with the increase in permeabi trast, and the oil increment of well P2 decreases as the channel permeability leve ence increases. When the channel permeability contrast is 1, the oil increment of is 130 t, which is less than 1343 t of P2. As the channel permeability contrast incr 20, the oil increment of P1 decreases to 85 t, and the oil increment of P2 decreases Subsequently, with further increase in permeability contrast, the oil increment production wells decreases slightly. When there is no main flow channel, the hig tion well present a higher oil increment. Figure 24 shows the comparison of P1 w before and after CO2 huff and puff. It can be seen that with the increase in perm contrast of inter-well channel, the water cut after CO2 huff and puff increases. Th cates that the higher the permeability contrast, the worse the water cur reduction   (2) Well Spacing For the single-well synergistic mode, five levels of 40, 60, 70, 80, and 120 m are designed to investigate the impact of well spacing on the performance of synergistic CO 2 huff and puff. The influence of well spacing on the oil increase and water cut is shown in Figures 25 and 26. The results indicate that for the lower-structural-position well P1, as the well spacing increases, the CO 2 swept volume increases. The lower the water cut after well stuffy, the higher the oil increase. When the well spacing exceeds 70 m, the higher-structural-position well P2 is less affected by the huff and puff of lower-structuralposition well P1. With the increase in well spacing, the total oil increment continues to increase. When the well spacing exceeds 70 m, the total oil increment decreases. These results indicate that CO 2 has a certain sweep radius after injection into the formation.  (3) Liquid production rate of high-position well The liquid production rate of high-position wells mainly affects the ga speed in the formation [46]. To clarify the influence of the high-position well duction rate on the performance of CO2 huff and puff, three levels of 20, 100, an are designed. Statistical results of the oil increase and water cut after well ope ferent liquid production rates are shown in Figures 27 and 28. It can be seen f 27 that with the increase in liquid production rate of P2, the oil increment of creases, whereas that of P2 well increases, and the oil increment of the well increases and then basically remains unchanged. From Figure 28, it is observ production water cut of well P1 after well stuffy decreases. With the increase in ing, the production water cut increases, and the water cut reduction capacity of CO2 huff and puff decreases.  (3) Liquid production rate of high-position well The liquid production rate of high-position wells mainly affects the gas speed in the formation [46]. To clarify the influence of the high-position well l duction rate on the performance of CO2 huff and puff, three levels of 20, 100, an are designed. Statistical results of the oil increase and water cut after well open ferent liquid production rates are shown in Figures 27 and 28. It can be seen fr 27 that with the increase in liquid production rate of P2, the oil increment of P creases, whereas that of P2 well increases, and the oil increment of the well increases and then basically remains unchanged. From Figure 28, it is observe production water cut of well P1 after well stuffy decreases. With the increase in ing, the production water cut increases, and the water cut reduction capacity of CO2 huff and puff decreases. (3) Liquid production rate of high-position well The liquid production rate of high-position wells mainly affects the gas migration speed in the formation [46]. To clarify the influence of the high-position well liquid production rate on the performance of CO 2 huff and puff, three levels of 20, 100, and 200 m 3 /d are designed. Statistical results of the oil increase and water cut after well opening at different liquid production rates are shown in Figures 27 and 28. It can be seen from Figure 27 that with the increase in liquid production rate of P2, the oil increment of P1 well decreases, whereas that of P2 well increases, and the oil increment of the well group first increases and then basically remains unchanged. From Figure 28, it is observed that the production water cut of well P1 after well stuffy decreases. With the increase in well spacing, the production water cut increases, and the water cut reduction capacity of synergistic CO 2 huff and puff decreases.

Multi-Well Synergistic Mode
The model parameters are consistent with the two-well and single-well synergistic modes. The difference from the other two models is that the typical model of multi-well synergistic mode has three horizontal wells. P1, P2, and P3 are located at the low part, middle, and high part of the structure, respectively. P1 and P3 perform CO2 huff and puff when water cut reaches 98%, and P2 maintains production in the process of huff and puff. In this mode, the only main control factor that we need to study is liquid production rate of the middle-position well.
The dissolution and distribution of injected CO2 are affected by the dynamic parameter of pressure and liquid production rate [47]. To clarify the influence of liquid production rate of middle well, three levels of 20, 100, and 200 m 3 /d were designed. The oil increment of each single well and well group are shown in Figure 30. Figures 30 and 31 indicate that the higher the liquid production rate, the lower the oil increment, and the worse the water cut reduction. Figure 31 shows the water cut of wells P1 and P3. It can be seen that the higher the liquid production rate of the middle well, the higher the water cut of the well, and the smaller the precipitation rate. Figure 32 shows the GOR of P2 well. The

Multi-Well Synergistic Mode
The model parameters are consistent with the two-well and single-well synergistic modes. The difference from the other two models is that the typical model of multi-well synergistic mode has three horizontal wells. P1, P2, and P3 are located at the low part, middle, and high part of the structure, respectively. P1 and P3 perform CO2 huff and puff when water cut reaches 98%, and P2 maintains production in the process of huff and puff. In this mode, the only main control factor that we need to study is liquid production rate of the middle-position well.
The dissolution and distribution of injected CO2 are affected by the dynamic parameter of pressure and liquid production rate [47]. To clarify the influence of liquid production rate of middle well, three levels of 20, 100, and 200 m 3 /d were designed. The oil increment of each single well and well group are shown in Figure 30. Figures 30 and 31 indicate that the higher the liquid production rate, the lower the oil increment, and the worse the water cut reduction. Figure 31 shows the water cut of wells P1 and P3. It can be seen that the higher the liquid production rate of the middle well, the higher the water cut of the well, and the smaller the precipitation rate. Figure 32 shows the GOR of P2 well. The The production GOR of P1 is shown in Figure 29. It can be seen that as production progresses, gas channeling occurs in the high-structural-position well. The higher the liquid production rate of the high-position well, the earlier the gas channeling but the smaller the maximum GOR. This is because the higher the liquid production rate, the higher the rate of CO 2 migration to high-position wells, and the earlier the gas channeling in high-position wells. When the liquid production rate is small, the CO 2 migration speed is slow. In the process of slow upward migration, a large amount of CO 2 is accumulated and stored between the wells. After the gas reaches the P1 well, the inter-well percolation resistance rapidly decreases, such that the CO 2 quickly migrates to the bottom of the well and the GOR rises sharply. When the liquid production rate is high, the CO 2 migration is relatively fast. During the upward migration process, there is less accumulated CO 2 ; thus, the maximum gas oil is relatively small. The simulation results indicate that the higher the liquid production rate of higher-structural-position wells, the earlier the gas channeling, the smaller the decrease in water cut after well stuffy of low-position well, and the smaller the oil increase.   The model parameters are consistent with the two-well and single-well synergistic modes. The difference from the other two models is that the typical model of multi-well synergistic mode has three horizontal wells. P1, P2, and P3 are located at the low part, middle, and high part of the structure, respectively. P1 and P3 perform CO2 huff and puff The model parameters are consistent with the two-well and single-well synergistic modes. The difference from the other two models is that the typical model of multi-well synergistic mode has three horizontal wells. P1, P2, and P3 are located at the low part, middle, and high part of the structure, respectively. P1 and P3 perform CO 2 huff and puff when water cut reaches 98%, and P2 maintains production in the process of huff and puff. In this mode, the only main control factor that we need to study is liquid production rate of the middle-position well.
The dissolution and distribution of injected CO 2 are affected by the dynamic parameter of pressure and liquid production rate [47]. To clarify the influence of liquid production rate of middle well, three levels of 20, 100, and 200 m 3 /d were designed. The oil increment of each single well and well group are shown in Figure 30. Figures 30 and 31 indicate that the higher the liquid production rate, the lower the oil increment, and the worse the water cut reduction. Figure 31 shows the water cut of wells P1 and P3. It can be seen that the higher the liquid production rate of the middle well, the higher the water cut of the well, and the smaller the precipitation rate. Figure 32 shows the GOR of P2 well. The higher the fluid production rate of the middle well, the more evident the gas channeling of CO 2 to the middle well.
rgies 2021, 14, x FOR PEER REVIEW higher the fluid production rate of the middle well, the more evident of CO2 to the middle well.

Sensitivity of Main Control Factors
The sensitivity degree is taken as an indicator to evaluate the sensitivit and is defined as: where S is the degree of sensitivity, and QOmax and QOmin are the maximum and oil increase, respectively. If the sensitivity degree is higher than 1.2, the consid is a very sensitive factor. When choosing a block for the implementation of CO2 huff and puff, this factor should be considered first, and its optimal value sh lected. If the sensitivity degree is higher than 1.1, the factor is a sensitive factor be considered when selecting the block that implements CO2 synergistic huf Figure 32. GOR of middle-well P2 with different liquid production rates.

Sensitivity of Main Control Factors
The sensitivity degree is taken as an indicator to evaluate the sensitivity of factors and is defined as: where s is the degree of sensitivity, and Q omax and Q omin are the maximum and minimum oil increase, respectively. If the sensitivity degree is higher than 1.2, the considered factor is a very sensitive factor. When choosing a block for the implementation of CO 2 synergistic huff and puff, this factor should be considered first, and its optimal value should be selected. If the sensitivity degree is higher than 1.1, the factor is a sensitive factor and should be considered when selecting the block that implements CO 2 synergistic huff and puff, but the value of this factor can be required. When the sensitivity degree is less than 1.1, the factor is an insensitive factor, which can be considered last in the constituency. The sensitivity of each factor is shown in Table 9. From the evaluation results, among the geological factors, the reservoir rhythm and permeability contrast of inter-well are extremely sensitive factors, the stratum dip is a sensitive factor, and the relationship with the isobaths is an insensitive factor. Among the development factors, well spacing, liquid production rate of high-position wells, and middle wells are extremely sensitive factors, and the injection volume allocation scheme is a sensitive factor.
Regardless of the synergistic huff-and-puff mode, geological factors are decisive for the implementation of the synergistic huff and puff. Reservoirs with a larger stratum dip show more evident gravity differentiation of CO 2 capacity, which is beneficial for tapping the residual oil in the high potential area and expands the action range of CO 2 . For the synergistic huff and puff based on horizontal wells, the reservoir rhythm is very important, and the bottom water rises slowly in the reverse rhythm reservoir, in which CO 2 huff-andpuff performance is the best. The positive rhythm oil reservoir can easily cause a horizontal ridge incursion due to the proper physical properties of the lower part of the reservoir, and the CO 2 validity period is short. The overall performance of synergistic huff and puff is poor. The influence of inter-well channels permeability contrast on synergistic huff and puff can be divided into two categories. The first class is conducive to synergistic huff and puff. For synergistic well groups with large well spacing, gas channeling is a medium for full contact between CO 2 and crude oil, which is conducive to the use of residual oil between wells. The other is adverse effects on synergistic huff and puff. Characteristics of this type include the residual oil saturation in adjacent wells of huff-and-puff wells, which are low and do not meet the conditions that can make the synergistic huff and puff effective, and injected gas channels along unsealed faults and the reservoir channel that connect the edge and bottom water. These conditions cause unnecessary consumption of CO 2 in the formation and reduce the contact area between CO 2 and crude oil.
Under different synergistic huff-and-puff modes, the concerned development factors are different. Under the two-well synergistic huff-and-puff mode, the injection volume allocation is a sensitive factor. For the same injection volume conditions, increasing the CO 2 injection ratio of the low part of the well is conducive for improving oil increment and water-cut reduction of CO 2 synergistic huff and puff.
In the single-well synergistic huff-and-puff mode, the liquid production rate of higherstructural-position wells is an extremely sensitive factor. The higher the fluid production rate, the earlier the gas channeling in the higher-structural-position wells, and the more serious the interference with the lower-structural-position wells. In this mode, well spacing is also an extremely sensitive factor. After the CO 2 is injected into formation, there is a limited migration distance. The small well spacing is conducive for producing residual oil between wells. If the well spacing is too large, the synergistic effect is weakened. In the multi-well synergistic huff-and-puff mode, the liquid production rate of the middle well is an extremely sensitive factor, and its intensity determines the migration velocity of CO 2 to the middle well. The higher the liquid production rate, the earlier the gas channeling, and the worse the synergetic huff-and-puff performance.

Adaptability of Synergistic Mode
Based on the actual development of various reservoirs at home and abroad, as well as the research results of the influence law of main control factors, from two aspects of reservoir conditions and development conditions, the applicable situations of different synergistic mode are proposed to guide the implementation of CO 2 huff and puff.
(1) Two-well Synergistic Mode For the actual areas which tend to conduct CO 2 synergistic huff and puff, the preferential selection are blocks with large stratum dips or well groups clearly controlled by microstructure. Large stratum dip angles are conducive to strengthening gravity differentiation. Priority is given to those oil reservoirs with positive sedimentary rhythm and larger oil layer thickness, which have higher potential for oil increment through CO 2 synergistic huff and puff. In addition, the heavy oil reservoirs with larger crude oil viscosity are a potential selection from the perspective of crude oil viscosity. Due to the large difference in fluid viscosity and the influence of static heterogeneity, the water cut quickly rises after water flooding development, and the residual oil near and between wells is rich.
For the areas that meet the implementation requirements of CO 2 synergistic huff and puff, development factors are another important consideration in the mode selection of CO 2 synergistic huff and puff. For development areas, the development well can be clearly divided into two-well rows. Reservoirs with strong edge and bottom water have inter-well channels when the well group is close to the oil-water boundary. The inter-well channel has a limited impact on the development performance of the two-well synergistic mode. Therefore, if there are inter-well channels, the two-well synergistic mode is recommended. The two-well synergistic mode shows a good tolerance of well spacing for the small oil increment difference between 40 and 80 m. The well spacing is better controlled within 120 m. CO 2 has a limited migration distance after injected into the formation, and excessively large well spacing is not conducive to balance the pressure between wells and inhibits gas channeling. For well groups with evident gas channeling channels, the well spacing can be appropriately enlarged.
(2) Single-Well Synergistic Mode The reservoir conditions required by this mode are similar to those of the two-well synergistic mode, except that there should be no dominant inter-well channels between injection and production wells. Comparing the influence of the dominant inter-well channel in the two modes on the development effect, it was found that the inter-well channel has a particularly large impact on the development performance of the single-well synergistic mode. When there are channels between wells, the total oil increment of the well group decreases by three times. Therefore, it is not recommended when there are numerous dominant inter-well channels with larger permeability contrast in the reservoir.
According to the change law of well spacing and well group oil increment, it was found that when the well spacing exceeds 70 m, the performance of huff and puff sharply deteriorates. If the reservoir development well spacing is higher than 70 m, this model is not applicable. Regardless of the synergistic mode, the well spacing should not be excessively large to achieve a good development performance.
(3) Multi-well Synergistic Mode This mode is a combination of the first two modes. The reservoir situation is similar to that of the two-well synergistic mode. If the reservoir development well pattern can be clearly divided into three well rows (high, middle, and low) and the liquid production rate of the middle well can be controlled, then this mode can be used for CO 2 synergistic huff and puff.
Synergistic huff-and-puff modes can be divided into two categories: one is a mode that is conducive to oil increment and water-cut reduction, and the other is a mode in which the performance is weakened by the existence of gas channeling. This type of mode needs to be reasonably avoided during the mode selection process.
Synergistic effects are beneficial to CO 2 synergistic huff and puff for increasing oil and precipitation. The situations conducive to synergistic performance are the cases in which the synergistic wells' ligature is perpendicular or parallel to the structural contour. When the synergistic wells' ligature is perpendicular to the structure isobaths, the following modes show good synergistic performance: (1) single-well huff and puff for horizontal and adjacent wells present synergistic effects due to gas channeling; (2) huff-and-puff measures are implemented for horizontal wells, and synergistic wells need to be located at the high structure part; (3) mixed well patterns of vertical and horizontal wells perform synergistic huff and puff.
Synergy effects not conducive to the performance of CO 2 huff and puff should be avoided. In the first case, the huff and puff's adjacent well is a continuous product with large liquid volume. In this case, inter-well interference occurs and easily induces gas channeling, which weakens the performance of huff-and-puff wells. In the second situation, there are channels between wells, but adjacent wells do not have synergistic conditions and exhibit low residual oil saturation. The unnecessary consumption of CO 2 in the formation caused by inter-well channel connected to the margin water leads to a decreasing contact area of CO 2 and crude oil. These two disadvantageous conditions can be mitigated by adjusting the production parameters or work regime of interfering wells, such as reducing liquid production capacity, closing the production well, or staggering the well's production time.

EOR Mechanism of Synergistic Huff and Puff
The application of synergistic CO 2 stimulation in multi-horizontal wells is targeted at well group units, and multi-well combined stimulation is adopted to enhance near-well residual oil production and to further excavate residual oil between wells. The synergistic CO 2 huff-and-puff mechanism includes: (1) Replenishment of formation energy, balance of the pressure distribution between wells, and suppression of gas channeling. When horizontal wells are produced, lowpressure areas are formed near the wells. The synergistic well group simultaneously injects gas, stuffs wells, and then opens wells, which unifies the working system of huff-and-puff wells and avoids gas channeling caused by pressure tendency surface formed during production of adjacent wells; (2) Gravity differentiation cooperation to tap potential residual oil of inter-well, high structural part, and top of oil layer; (3) Inhibition of static heterogeneity. After stuff, the well is opened to produce oil, and a large amount of foam is generated when the side and bottom water displace CO 2 . The formed foam increases the additional pressure in the porous medium and strengthens the Jamin effect. The Jamin effect reduces the water-phase percolation capacity of the high water-cut layer, which suppresses the effects of water channeling and gas channeling caused by static heterogeneity and ultimately improves the utilization degree of crude oil enrichment area; (4) The coupling effect of dynamics and oil reservoirs suppresses the impact of dynamic heterogeneity. In the process of synergistic huff and puff, the dissolution and distribution of CO 2 are affected by the dynamic parameter of pressure and fluid production rate.

Oilfield Overview
The C2X1 fault block is located in Jidong oilfield with a depth of 1700 m and a main layer NG13 and presents the following characteristics: average permeability of 700 mD, average porosity of 26%, formation pressure of 17 MPa, pressure coefficient of 0.97, reservoir temperature of 60 • C, formation crude oil density of 265 mPa·s, and surface crude oil density of 0.96 g/cm 3 . It is a typical structurally controlled small fault block ordinary heavy oil reservoir with edge and bottom water. This fault block has seven horizontal production wells, but there is no injection well.

Application Senario
CO 2 synergistic huff and puff was conducted on 15 April 2014. The CO 2 injecting wells are C2-P2, C2-P3, and C2-P6. The adjacent wells that need to be observed are C2X1, C2-3, C2-P4, and C2-P5. C2-3 and C2-P4 are closed during the gas injection process. Well C2-P1 is permanently closed. The locations of CO 2 synergistic huff-and-puff wells are shown in Figure 33, and the implementation plan is presented in Table 10.

Energies 2021, 14, x FOR PEER REVIEW
The C2X1 fault block is located in Jidong oilfield with a depth of 1700 m layer NG13 and presents the following characteristics: average permeability average porosity of 26%, formation pressure of 17 MPa, pressure coefficient o voir temperature of 60 °C, formation crude oil density of 265 mPa.s, and surfa density of 0.96 g/cm 3 . It is a typical structurally controlled small fault block ord oil reservoir with edge and bottom water. This fault block has seven horizontal wells, but there is no injection well.

Application Senario
CO2 synergistic huff and puff was conducted on 15 April 2014. The C wells are C2-P2, C2-P3, and C2-P6. The adjacent wells that need to be observe C2-3, C2-P4, and C2-P5. C2-3 and C2-P4 are closed during the gas injection p C2-P1 is permanently closed. The locations of CO2 synergistic huff-and-pu shown in Figure 33, and the implementation plan is presented in Table 10.

Performance Evaluation
Statistics and calculation of parameters, including production GOR, oil increment, water cut, working fluid level, and daily liquid production volume before and after the CO 2 synergistic huff and puff, are performed to evaluate the performance of CO 2 synergistic huff and puff. The CO 2 EOR mechanism reduces crude oil viscosity, crude oil volume expansion, extraction, light hydrocarbons, and dissolved gas flooding in vaporized crude oil, which reflects the oil increase ability [48,49]. The oil increment of synergistic CO 2 huff and puff is the most intuitive parameter to characterize the oil increase ability. The effect of CO 2 huff and puff is in addition to oil increase and water-cut reduction. When the CO 2 injection well is opened for production, the edge and bottom water form a large amount of foam during the process of displacing CO 2 , which increases the additional pressure in the porous medium and reduces the water-phase percolation capacity of the severe water flooded layer. The enhancing mechanism is reflected in the reduction of water cut in production. Therefore, the water cut reflects the ability of CO 2 water-cut reduction. In the process of oilfield development, insufficient formation energy causes a rapid decline in production and reduces recovery efficiency [50,51]. The injection of CO 2 can supplement the formation energy balance pressure distribution between wells and decelerate the gas channeling to improve oil recovery. The changing tendency of the working fluid level and daily liquid production reflects the ability of injected CO 2 to supplement the formation of energy. Through the changes of the moving liquid level and liquid production, it can be known whether the injected CO 2 has supplemented the formation energy.

Oil Increment
In this CO 2 synergistic huff-and-puff stimulation program, all CO 2 injection wells are effective, and C2-3 and C2-P4 wells in adjacent wells are synergistically effective, but C2X1 and C2-P5 are not effective. The performance of each well is shown in Table 11. The oil increment of effective wells is higher than that of synergistic effective wells. The total oil increment is 6400.7 t, and the CO 2 synergistic effective well increases oil by 995.84 t; thus, the synergistic efficiency is 50%. Statistics of the oil increment of production wells at different structural positions indicate that the oil increment of C2-P3 in the lower structural part is significantly less than that of wells in the high structural position, which is shown in Figure 34. The oil increment of 1878.54 t is significantly lower than the oil increment of the high part wells of 4521.16 t. The reason for this performance is that under the action of gravity differentiation, the injected CO 2 migrates upwards; thus, the amount of CO 2 acting on the high part wells is larger. The effectiveness of C2-3 and C2-P4 is mainly caused by the CO 2 huff and puff of well C2-P2; thus, the oil increment of wells in higher structural positions is better than that in low positions. 0.10 no effect N

Water-Cut Reduction
The water cut of the effective wells is shown in Figure 35. After the wells are opened, the water cut of the synergistic effective wells, C2-3 and C2-P4, slightly decrease and then rise until they return to the level before the huff and puff. After well opening, the water cut of CO2 huff-and-puff wells is very low, less than 20%. After nearly 11 months, it slowly rises to the level observed before the well is opened, indicating that the CO 2 huff-and-puff well has a good water control effect. For synergistic wells, the water cut is higher than that of effective wells, and the water cut exhibits a downward tendency after the well is opened for some time. This indicates that as the production proceeds, CO 2 migrates to the synergistic well, and the water control effect is evident. As the production progresses, the water cut begins to rise. This is due to the limited amount of CO 2 that migrates to the synergistic well; thus, the water control effect time is short. Figure 36 shows a comparison chart of water cut before and after the well is opened. The water cut of the first five effective wells of the huff and puff is close to 100%. After well stuffy, the water cut significantly decreases, which shows that the CO 2 has a better water control effect. The average water-cut reduction of CO 2 synergistic huff and puff is 57.7%. rgies 2021, 14, x FOR PEER REVIEW

Water-Cut Reduction
The water cut of the effective wells is shown in Figure 35. After th the water cut of the synergistic effective wells, C2-3 and C2-P4, slightl rise until they return to the level before the huff and puff. After well cut of CO2 huff-and-puff wells is very low, less than 20%. After nearly rises to the level observed before the well is opened, indicating that th well has a good water control effect. For synergistic wells, the water cu of effective wells, and the water cut exhibits a downward tendency afte for some time. This indicates that as the production proceeds, CO2 m gistic well, and the water control effect is evident. As the production p cut begins to rise. This is due to the limited amount of CO2 that migrat well; thus, the water control effect time is short. Figure 36 shows a c water cut before and after the well is opened. The water cut of the firs of the huff and puff is close to 100%. After well stuffy, the water c creases, which shows that the CO2 has a better water control effect. Th reduction of CO2 synergistic huff and puff is 57.7%.

Formation Energy Supplement
The daily liquid production volume of the effective wells is shown in Fig  indicates that the daily liquid production of each well has significantly incre pared to that before the implementation of synergistic CO2 huff and puff. Figur the working fluid level of effective wells, and it can be seen that the working flu C2-P2 well decreases from 230 to 300 m, that of C2-P3 well rises from 250 to 2 the working fluid level of C2-P6 slightly rises. The working fluid level of syn fective well C2-P4 significantly rises from 600 to 300 m. The rise of daily liquid p volume and working fluid level indicates that the CO2 synergistic huff and pu plemented the formation energy and reduced the decline rate of reservoir deve

Formation Energy Supplement
The daily liquid production volume of the effective wells is shown in Figure 37 and indicates that the daily liquid production of each well has significantly increased compared to that before the implementation of synergistic CO 2 huff and puff. Figure 38 shows the working fluid level of effective wells, and it can be seen that the working fluid level of C2-P2 well decreases from 230 to 300 m, that of C2-P3 well rises from 250 to 200 m, and the working fluid level of C2-P6 slightly rises. The working fluid level of synergistic effective well C2-P4 significantly rises from 600 to 300 m. The rise of daily liquid production volume and working fluid level indicates that the CO 2 synergistic huff and puff has supplemented the formation energy and reduced the decline rate of reservoir development.

Conclusions
Based on the characteristics of fault-block reservoirs with small oil-bearing