Abstract:Aiming at oil and gas accumulation in the Paleogene red beds in Boxing subsag，Dongying sag，a north-south strike section Jin26-Binxie703 was chosen as main research object. A quantitative relationship between the probability of hydrocarbon accumulation in the study area and the distance from hydrocarbon reservoir to hydrocarbon kitchen was set up by using a statistical method，the reservoir paleo-physical properties were researched using the corresponding present reservoir physical properties charts and the dynamic evolution history of hydrocarbon reservoir during key hydrocarbon accumulation was restored through basin modeling constrained with procedure. The results show that the distribution of red beds hydrocarbon reservoirs is correlated better with the distances from the reservoirs to the center source or to the source boundary in Boxing subsag，which is characterized by Gauss normal distribution，so as to establish the quantitative model of oilgas accumulation probability that is controlled by source rock. Reservoir physical properties that can reflect“facies”change significantly during the key hydrocarbon accumulation period，and the residual fluid pressure of formation that can reflec“t potential”mainly comes from abnormal pressure of formation in Boxing subsag. The relationship between“facies”and “potential”can be characterized quantitatively finally by using the corresponding formula to calculate the“source-faciespotential”coupling index which can be used to predict favorable reservoir zones based on the relationship between these indexes and the reservoirs that has been found in the red beds. In the section Jin26-Binxie703，all the hydrocarbon reservoirs found at the lower sub-segment of the 4th member of Shahejie Formation and Kongdian Formation locate in the zone with“source-facies-potential”coupling indexes above 0.5. During the hydrocarbon accumulation period，coupling indexes of the zones on the north of Well Fan141 are comparatively high，all above 0.55，which can be favorable exploration areas for further exploration.

Abstract:With the new oil-bearing formations and types of reservoir found in Kendong area in recent years，it is necessary to reconsider the petroleum migration and accumulation law accordingly. The main and priority migration pathway of different oil-bearing formations were studied by using seismic data，geological data and new well logging data of the area. It is shown that there are two different petroleum migration and accumulation sub-systems in the Neogene and the Paleogene respectively. For the Neogene system，the oil and gas migrated laterally through two paths that were strike slip faults and sandstone framework during the tectonic active period，and the paths were named as fault-sandstone system and sandstonefaults system respectively. For the Paleogene system，the oil and gas migrated slowly through the single path that was the unconformity for hydrocarbon transporting laterally during the tectonic stable period，and the path was named as fault-unconformity system. The petroleum migration and accumulation model of“two-story platforms”was built according to the differences of the migration medium and their priority pathway between two oil and gas bearing formations.

Abstract:The pores in reservoirs bearing hydrocarbon have been divided into three types：millimeterpore，micropore and nanopore. The diameter of pore throat in conventional reservoir is generally larger than1 μm. The diameter of pore-throat in tight gas reservoirs ranges from 0.03 to 1 μm. The nanopore is the main body of the connected reservoir space in tight sand，so it is difficult to evaluate the effectiveness of tight reservoirs. Both NMR T2 spectrum and capillary pressure curves can well reflect the pore throat structure of rocks. The NMR T2 spectrum was translated into pore throat distributions using the correlation between NMR T2 experiment and mercury injection. On the basis of previous research results，the core NMR T2 spectrum and capillary pressure data were processed and analyzed deeply to determine effectiveness criteria of the tight sand pore throat in SLG oilfield：the pore-throat system with pore radius less than 0.04 μm is associated with clay bound water volume；the pore-throat system with a pore radius between 0.04 and 0.1 μm is associated with non-shale micro-porosity formation water volume；the pore-throat system with pore radius between 0.1 and 0.2 μm is associated with capillary bound water volume；the pore-throat system with pore radius more than 0.2 μm is associated with the volume in which the fluid can be taken out. The practice proves that the method can be used to quickly calculate pore-throat space quantitatively and to determine the pore water features and its occurrence，which can evaluate the space effectiveness of tight sand reservoirs effectively.

Abstract:In order to study the geological structure characteristics of unconventional tight sandstone and shale reservoir，the relationship between vp/vs and rock lithology，physical properties，poisson ratio，stress and micro cracks of the deep tight sandstone and mud shale was studied based on the data of physical test，mechanical test and acoustic test of Triassic rocks in west Sichuan area. The results showed that vp/vs can distinguish lithology effectively；vp/vs has a positive correlation with porosity and permeability for the formations having the same lithology；abnormally high vp/vs can always occur with the formation of micro cracks under high stress；the rise of vp/vs and the decline of vs both can indicate the development degree of the micro cracks. In the study area，vp/vs is more sensitive to the cracks. vp/vs was characterized and calculated by using poisson ratio and Gassmann equation respectively. It shows that these two methods both have a certain applicability，but the Gassmann equation has a much higher accuracy. A conclusion can be drawn that the theory of elastic wave in the complex formations of tight sandstone and shale is applicable.

Abstract:Putaohua oil layer of Daqingzi well area in southern Songliao Basin is sandstone reservoirs with low-medium porosity，low permeability and thin layer. The characteristics，spreading regularity and quality controlling factor of the peripheral sand body reservoirs are unclear. The reservoir characteristics have become a restrictive factor of the exploration and development. The reservoir characteristics were researched based on cores，casting thin sections and conventional mercury injection and other analytical data. The result shows that the sand body in the braided channel crotch will be the favorable reservoirs with rock type of debris arkose and pore type of secondary dissolution pore and residual primary pore. It has welldeveloped pore structure as medium-porosity and medium-throat type. Daily production by oil test is high. Sedimentation is the basic factor and dissolution among diagenesis is the key factor for the formation of favorable reservoirs in the braided channel crotch.

Abstract:The internal texture characteristics of sandy conglomerate have not been understood clearly in the nearshore subaqueous fan of the upper fourth member of Shahejie Formation（Es4s）in Yanjia area，Dongying sag. Based on core delineation，the sandy conglomerate bodies are divided into 11 types of lithofacies as well as 13 types of lithofacies assemblages of Es4s in the area. The rock textures are summarized into three categories and six subcategories. Formation MicroScanner Image（FMI）chart modes of typical lithofacies are established according to core type recognition. The lithology identify curve（LIC）can be reconstituted by conventional logging data，which is calibrated by core and FMI to be used to establish LIC quantitative standards of typical rock textures. The rock texture types of a single well were identified by this method in Yanjia area. Longitudinal distribution of rock texture of sandy conglomerate was analyzed based on well-connecting profile.The vertical superposition modes of rock texture in different subfacies of the nearshore subaqueous fan were established.The analysis suggests that single stage sandy conglomerate deposit is a sequential combination of mudslide deposit，flood deposit and tractive current deposit vertically which extends towards the basin in a wedge shape and constantly retrogradestowards the boundary fault vertically.

Abstract:The Kendo-Chengdao structural belt is an important hydrocarbon-bearing belt in the northeast of the Jiyang depression. The formation mechanism of individual fault was determined through analyzing Paleogene stress field characteristics and fault activity features，thus the reasons for the formation of uplifts and their relationship were clarified. The results show that three series of pre-Cenozoic basement faults developed striking NW，NEE and NNE respectively in the area.The first two are thrust faults generating at middle Triassic-Indo during pre-continent deformation，while the last one is the strike-left-slip fault accompanying with Tan-Lu Fault System translation at the late Jurassic. During the regional tension in south and north at Paleogene in the area，the basement faults striking NW moved again in left-tensional-shear，while the basement fault striking NNE moved again in right-tensional-shear. To the Cenozoic，the new generating faults striking nearly WE developed under the force of tensile stress in the south and north. The uplifts are characterized by tension-torsional half horst structure resulted from multiple activities of multi-faceted fault，which constitute together a composite Kendong-Chengdao structural belt.

Abstract:Sulige gasfield is a typical fluvial tight sandstone gas reservoir. The effective reservoir of the gas reservoir is thin with various superimpose and complex structure. The reservoir has strong heterogeneity both in the horizontal and vertical and it is difficult to be finely described. As a result it is difficult to model the gas reservoir accurately. Either conventional deterministic or stochastic method can not make a satisfied sedimentary facies model because of their limitations when they were used alone，and the geological model obtained agrees poorly with the associated dynamic simulation. As a case from the Su6 infilling well experimental area in Sulige gasfield，an effective reservoir modeling method was built combining deterministic sedimentary facies modeling with stochastic sedimentary facies modeling to control and constraint gradually sedimentary facies modeling based on sedimentary microfacies study，effective reservoir size and distribution. The accuracy of geologic modeling could be improved through synthesizing advantages of the single conventional modeling method and being constrained by dynamic and static parameters. A history matching coincidence rate is 52.4%，which indicates that the new method can model the actual situation of the reservoir better.

Abstract:The reservoir-forming mechanism was studied by analyzing 17 oilfields and 69 blocks in the Jiyang depression statistically and by anatomizing 5 blocks typically，and then the reservoir-forming difference of stratigraphic reservoir was analyzed. The results show that opening and sealing properties of oil source fault control the directions of oil and gas migration；positive tectonic background controls the stratigraphic reservoir enrichment；unconformity structure controls the stratigraphic reservoir types，and reservoir-forming dynamics controls the hydrocarbon potential of the stratigraphic trap. The mi? gration mode along oil source fault for basin margin stratigraphic trap in Jiyang depression are mainly lateral，vertical as well as along the strike. The stratigraphic reservoirs with different mode of hydrocarbon migration are different in scales.There are also differences in reserves due to different types and entrapping horizons of stratigraphic traps. The reserves of stratigraphic reservoirs in Neogene Guantao group and the stratigraphic overlap reservoirs are the largest. There are differences found in stratigraphic reservoirs developed at the same type of structural belts in different sags or at different structures in the same sag. There are overlap reservoirs and truncation unconformity reservoirs in the gentle slope belts，the reserves scale of which are larger with little difference. In the steep slope，there are mainly overlap unconformity reservoirs.

Abstract:Reservoir developed well in the third member of Eogene Shahejie Formation with various kind of sandbodies.Since the evolution history and distribution diversity of sedimentary system are not fully understood，exploration of lithologic reservoir and structural-lithologic reservoir are greatly restricted in west Shuangfeng area and east Jiangjiadian area.Based on well data and seismic data，the palaeo geomorphology，palaeo shoreline，and synsedimentary faults were analyzed systematically，and the palaeo-depositional setting of the third member of Shahejie Formation in the area was restored，also the filling diversity of sedimentary system and control factors were clarified，and finally two kinds of depositional models were established. In the south part，sedimentation was controlled by the relationship between provenance direction and depression faults，and the fault activity also played its role. In the west part，Shuangfeng delta intersected with dispersed end of Xiakou fault，which makes progradation toward the lake；weak fault activity and gentle slope resulted in stable delta through long distance progradation，while sandbodies of braided river developed in delta plain subfacies greatly with low ratio of sandstone to clay. In the east part，Jiangjiadian delta and Wawu delta intersected uprightly with Xiakou fault，which makes progradation toward the lake；intense and long-term fault activity and steep slope resulted in synsedimentary faulted delta through short distance progradation，while sandbodies were transported rapidly into the lake and piled up quickly to develop mouth bars with high ratio of sandstone to clay.

Abstract:In order to investigate the relationship between the methylphenanthrene index（MPI1）and the vitrinite reflectance（Ro），the extracted chemical composition of marine shale that dominated by type Ⅱ kerogen and the aromatics fraction in its related crude oil in the Upper Cretaceous of a basin in Western and Central Africa Rift Systems were analyzed using gas chromatography-mass spectrometry（GC-MS）technology. According to the distribution patterns of phenanthrene and methylphenanthrene and other polycyclic aromatic hydrocarbons，the relationship between the methylphenanthrene index and the vitrinite reflectance of the source rocks in this area was researched，and the maturity of source rocks and the related oils in this basin were evaluated. It shows that the Ro value has an excellent positive linear correlation with MPI1 ranging from 0.50% to 0.90% with a coefficient of 0.92. This equation is significantly different from that proposed in previous literature based on coal and type Ⅲ kerogen. The difference of Ro value between the immature to low mature stage and high mature stage after oil window can approximately reach 0.2%. Therefore，it can cause significant effect on thermal maturity of the organic matter in the source rocks and hydrocarbon resources assessment. The oil maturity was evaluated by this equation. The results are in good agreement with the geological background of this basin.

Abstract:The reservoirs of Xujiahe Formation in northeastern Sichuan basin，with low porosity and permeability，are typical tight sandstone reservoirs. The exploration results show that the main types of reservoir fluid are gas（gas with low resistivity），gas-bearing water，dry layer and water. But there are difficulties in accurately identifying the types of fluid in tight sandstone reservoirs，which has became a restriction during the exploration and development of Xujiahe Formation. Based on the above problems，after analyzing the reasons of the difficulties in accurately identifying reservoir fluids，two types of regular methods were proposed to identify Xujiahe tight sandstone reservoir fluids in northeastern Sichuan basin and the advantages and disadvantages of each method were analyzed. At the same time，the paper attempted to use Fisher discriminatory analysis to identify reservoir fluid. The canonical functions derived from Fisher discriminatory analysis could be used to easily distinguish reservoir fluid. The coincidence of the obtained results were 92.3% with the actual production situation，which showed that better effects could be obtained by this method in identifying types of fluid in tight sandstone reservoirs in the work area.

Abstract:In low permeability reservoirs，it is essential to exactly know the rule of fluid flow in porous media during waterflooding development. The relative permeability curve may intuitively reflect the characteristics of the oil and water seepage in porous media. The study of factors affecting the relative permeability curve mainly focuses on the inherent properties of rock（wettability and pore structure），flow medium（oil and water viscosity ratio），water dynamic condition（displacement pressure gradient and velocity），etc. The impact of the formation pressure on the relative permeability curve in the low permeability reservoirs has seldom been studied. Through mercury-injection experiment，the decline process of the formation pressure was simulated，and the relative permeability curves in the low permeability reservoirs under different levels of formation pressure maintenance were established. The variation of the oil and water seepage in the low permeability reservoirs was analyzed. The results of experimental study show that when the heterogeneity of pore structure becomes stronger and the formation pressure goes down，the oil-phase relative permeability declines and the water-phase relative permeability rises，and also the isotonic point shifts to the left and the two-phase region turns narrow，resulting in the increase of residual oil saturation. That is，the stress sensitivity exists in the oil-water seepage in the low permeability reservoirs. Analyses have shown that the elastic or plastic deformation in the reservoir rocks is the root cause of the stress sensitivity of the oilwater seepage characteristics. Thus the development philosophy of the low permeability reservoir has been put forward：the lower the initial permeability of the reservoir rocks is，the earlier the waterflooding time should be.

Abstract:Non-Darcy flow and permeability anisotropy are the essential characteristics of the extra-low permeability reservoir. In order to solve the theoretical calculation problem of areal sweep efficiency for the extra-low permeability anisotropy reservoir，non-Darcy stream tube model was built taking the threshold pressure gradient into account，and the areal sweep efficiency formula and water breakthrough time formula of five-spot well pattern were derived by using of coordinate transformation method to change anisotropy reservoir into an equivalent isotropy reservoir. This method can be used to quantitatively characterize the produced degree of the extra-low permeability anisotropy reservoir by water flooding，and provide theory basis for development and evaluation of the extra-low permeability anisotropy reservoir. Taking an extra-low permeability anisotropy reservoir of Ordos Basin as an example，we analyzed the effect of threshold pressure gradient，permeability anisotropy，well spacing and pressure difference on areal sweep efficiency with this method. The case study shows that when the permeability anisotropy degree is strong，the injected water will preferentially flow along the high permeability direction resulting in the unbalanced development. The adjustment of well spacing and row spacing，the rise of pressure difference and well pattern infilling are effective measures to decrease the dead-oil zone and to increase water flooding swept area.

Abstract:Multi-staged fracturing for the horizontal well is the key technique of tight oil reservoir development. Due to the complexity of the in-situ stress and the impact of natural fractures，there is usually a certain angle between the hydraulic fractures and the wellbore，which makes the production forecast of the fractured horizontal well very difficult. Based on the equivalent permeability tensor theory in naturally fractured reservoir，a steady flow mathematical model has been established in the tight oil reservoir with full permeability tensor. By combining the half-analytical method that considering stress sensitivity with potential superposition principle，a discrete potential function unit of the flow from matrix to artificial fractures was formed. The flow in the fractures is considered as linear flow among the discrete units，and the matrix and fracture flow are coupled and solved. A computational method for productivity of arbitrary angular fractured horizontal well under the condition of the natural fractures was given. The result of a practical case shows that the error between the computing results and the field data is less than 7% for considering the effect of the angle of the natural and artificial fractures.Sensitivity analysis indicates that the angle between the primary permeability and the hydraulic fracture has a significant impact on the horizontal well productivity.

Abstract:The stress-dependent permeability in the heterogeneous tight sandstone has been studied based on the experiment of permeability stress sensitivity. Based on Hertz contact deformation principle，a capillary model for heterogeneous tight sandstone was established to characterize the stress sensitivity of capillary and porous media. The variation of porosity，permeability and permeability ratio under different effective stress was quantitatively analyzed. The theoretical calculation results were compared with the experimental ones as validation，and the experimental results were explained in theory. Research results show that the stress sensitivity of the heterogeneous tight sandstone is mainly presented as permeability stress sensitivity. Rock permeability varies with effective stress in different cores. The lower the rock permeability is，the faster the permeability declines. The permeability declining speed of the heterogeneous rock lies between those of the high permeability layer and the low permeability layer. When the permeability ratio increases，the stress-dependent permeability curves of heterogeneous rock are closer to that of the low permeability layer in rock. Heterogeneous tight sandstone permeability ratio becomes larger when effective stress increases.

Abstract:Common phenomenon of stress sensitivity in the tight reservoirs may result in great decline of production after producing for some time for the oil wells. According to the development problem of the tight reservoirs in WHZ oilfield，T2 testing method through core NMR was applied to obtain pore-throat radius and T2 cutoff value and other parameters. The microscopic characteristics of rock composition，the pore-throat structure and the distribution of porosity and permeability in the tight reservoirs of WHZ oilfield were analyzed. Based on the experiment of core flooding and the method of statistical analysis，the variation of core permeability with the confining pressure was understood，and the function relationship between dimensionless permeability and dimensionless confining pressure for the tight reservoirs was researched. Influencing factors on medium deformation for the tight reservoirs were analyzed and the oilfield production situation under various development modes was analyzed combined with the actual field situation. The result shows that the permeability damage of porous medium is irreversible under loading and unloading confining pressure for the tight reservoirs in WHZ oilfield，and the re-distribution of pore-throat structure may be affected in the process of pressure drop. It’s hard to recover the initial value and permanent damage may form for the reservoir even if energy is supplemented. Actual data of the WHZ oilfield show that the productivity loss may occur under pressure drop and the productivity with synchronous water flooding may be higher than that with no water flooding. Therefore，a reasonable formation pressure is necessary in the process of oilfield de? velopment，which may avoid production loss resulted from medium deformation of the reservoirs.

Abstract:Injection water is the main way to supply formation energy in the low permeability reservoirs，and water quality is the key influencing factor of water flooding effect. Related salinity index of the injection water was not proposed by the recommended specification of the injection water quality using in the low permeability reservoir. There are no standards for dividing the reservoir with permeability less than 10×10-3 μm2. The throat distribution difference and the contribution of the dominant throat to the permeability were analyzed through constant velocity mercury injection experiment，and the key throat intervals influencing injection water effect in different permeability reservoirs were obtained. The effects of clay particle migration and hydration expansion on seepage capacity were analyzed quantitatively. The limits of water salinity，particle size and particle concentration with different permeabilities in the low permeability reservoir were initially proposed by laboratory core physical simulation of water flood combined with throat distribution. The results show that if core permeability is lower，the injection water salinity is closer to the formation water salinity；the damaged degree on reservoir seepage capacity is deeper with larger particle size or higher water particle concentration.

Abstract:There are two sets of conjugate shear fractures in the NE-SW and N-S orientations in Chang6 reservoir，Ansai oilfield. But the watered direction was inconsistent with the nature fractures. On the basis of analyzing the nature fractures characteristics，the produce curves，the injection index curves，the intake profiles and the time-lapse well test in different development stages of Wangyao area were used to study the response characteristics of dynamic fractures. Because of the increasing water injection pressure，the closed nature fractures opened selectively，expanded and connected oil and water wells，which caused the water flooding of oil zones. According to the Coulomb-Mohr shear failure theory and Griffith failure criteria，the opening pressures of dynamic fractures are 20-23 MPa and the ultimate extension directions are NE 60°-75° which is consistent with the current maximum horizontal major stress direction. The dynamic fractures aggravate the reservoir heterogeneity and cause the quick water flooding along the current maximum horizontal major stress direction，which reduces the producing degree horizontally and vertically and influences the reservoir development effects.

Abstract:Imbibition function of fluid in the fracture and matrix is a very important mechanism in low permeability reser? voir during water flooding. The oil displacement process of different low permeability cores was studied by imbibition experiment. The result shows that the imbibition process in this type of oil reservoir is an inverse imbibition controlled by higher capillary force in the system，and the capillary force is helpful to the displacement process in imbibition. The imbibition production mainly occurs in the early imbibition process，and becomes fewer and fewer after 50 h in the later period，and there is almost no production in the final period. Mostly，the imbibition oil recovery of the fractured low permeability reservoir is 12% in average and increases with the permeability. But when the permeability is more than 2×10-3 μm2，the imbibition oil recovery has few increases. Better pore structure is favorable to spontaneous imbibition. Calculated by isometric method，the experimental result may be applied to forecasting the actual oilfield development for various cores and reservoirs.

Abstract:Laboratory displacement experiment of chemical steam flooding in different temperature regions has been carried out because of low oil displacement efficiency and sweep efficiency of the steam flooding in Zhongerbei Ng5 of Gudao oilfield，Shengli petroliferous province. There are three different temperature zones from the injection wells to the production wells：steam zone，hot water condensation zone and reservoir temperature zone. The displacement characteristics of the chemical steam flooding in different temperature regions were studied from displacement efficiency and injection pressure.The results show that foam produced by foaming agent solution could plug big channel in porous media and prevent steam breakthrough and superheating water fingering in the steam zone and hot water condensation zone. Injection pressure could be increased by 4.0 MPa and 1.6 MPa respectively at the best mass fraction of foaming agent（0.3%）in the steam zone and hot water condensation zone. In the reservoir temperature zone，the foaming agent and displacement agent only act as surfactant flooding and the displacement agent played important role in the driving process.

Abstract:The integrated oil reservoirs have stepped into extra-high water cut stage. Original technologies don’t fit to the current development situation，and the design of horizontal wells has become more difficult and the development effect is restricted to the deficient understanding about oil-displacement mechanism of horizontal wells at this stage. A large-scale consolidated model was built based on the similarity criterion in physical simulation according to the practical production data. Enhancing the oil recovery by the horizontal wells was studied. EOR mechanism of the horizontal wells can be re? vealed through the introduction of contribution rate of oil displacement efficiency and contribution rate of sweep efficiency.The influence of vertical permeability ratio，interlayer permeability，horizontal wells direction and the drilling time on oil recovery were studied with numerical simulation. The result shows that sweep efficiency may be improved at early stage of production and the oil displacement efficiency should be enhanced in the extra-high water cut stage for the horizontal wells.The horizontal well is more perpendicular to the line of injection wells the higher the vertical permeability ratio is and the lower the interlayer permeability is. The contribution rate of oil displace efficiency is higher at the same water cut the earlier the deploying time of horizontal well is and the lower the contribution rate of sweep efficiency is.

Abstract:KBM oilfield belongs to unconsolidated sandstone heavy oil reservoir. It is difficult to control the water cut and make oil production stable for the water cut rises quickly and the oil production declines greatly in the process of development. Efficient development measure should be taken through experimental research. According to the characteristics of the oilfield，combined plugging agents such as polymer water swelling and polymer gel were applied. During April to August 2013，a deep profile control experiment was made in the G and D layers of the oilfield central area. The average amount of the injected plugging agents is 2 187 m3 in each well. The results showed that the injection pressure raised by 1.5 MPa averagely. The injection profile was improved apparently：the swelling thickness of the main layers in oil well 420 raised from 5.5 m to 9.5 m and the swelling strength of the main layers dropped from 11.2 m3/m to 3.2 m3/m. The effect of oil production increases was obvious in the response producer：82.6% of the total 23 oil wells had good response. Composite water cut dropped from 88% to 83%. Accumulated annual oil production increased to 13 408 t. The effective period of the profile control and water plugging was more than 12 months long. The resistance factor rises to 3.26 based on the calculation and analysis. The formation flow resistance decreased obviously after profile control and flooding. A profile control system that fits for the unconsolidated sandstone heavy oil reservoir and has both effects of profile control and flooding is suggested to be optimized and used in the oilfield development.

Abstract:Micro-seismic monitoring，as a technique for the design，implementation and evaluation of hydraulic fracturing volume reformation，has been developing rapidly with the large-scale development of unconventional hydrocarbon reservoir.The sand-gravel reservoir in Yan227 wellblock of Dongying sag has low porosity and very low permeability. Based on micro-seismic monitoring data acquisition and processing of Well Yan227-3HF and Well Yan227-8HF，the development of artificial fracture space，including its length，width，direction and height，and its effective rang were analyzed at first through the methods of vertical projection of micro-seismic event point，side projection，calculating of fracturing volume and fracturing frontal area，etc. And then data from drilling，logging，well logging，3D seismic and fracturing construction process parameter curve were comprehensive utilized，thus the characteristics of natural fracture distribution，the lithology and sedimentary facies belt of each fracture section and their influence on spatial distribution of artificial cracks were analyzed. Finally，the unconventional hydrocarbon reservoir fracturing effect was evaluated comprehensively in Yan227 well? block area. The results show that the middle-fan section is easier to be fractured compared with the fan root; pebbly sandstone with relatively thick layer has better fracturing effect than the one with thinner layer and multi-interbedded mudstone.