苏里格气田是中国致密砂岩气田的典型代表，其储层物性差，有效砂体规模小，分布频率低，非均质性强，区块之间差异明显。依靠600 m×800 m的主体开发井网难以实现储量的整体有效动用，采收率仅约30%，需要开展储量分类评价，针对各类储量区分别实施井网加密调整。优选气田中部苏14区块为研究区，通过密井网区精细解剖、干扰试井分析明确了储层的发育频率及规模；以沉积相带为约束，结合储量丰度值、储层叠置样式、差气层影响和生产动态特征，将气田储量分成5种类型。从I类—V类，储层厚度减小，连续性变差，储量品位降低，单井产量变低。依据密井网实际生产数据与数值模拟结果，针对各储量类型，研究了井网密度、干扰程度和采收率的关系，论证了合理井网密度下的单井开发指标。在现有的经济及技术条件下，各类储量区合适井网密度为2~4口/km²，气田最终采收率约为50%。通过系统研究确定了致密砂岩气田复杂地质条件下的储量构成，为开发中后期加密调整方案的编制提供了地质依据。

采用物理模拟实验与数学评价方法相结合，系统研究了井控范围从500 m逐步加密至100 m(相当于井距从1 000 m加密至200 m）过程中不同渗透率砂岩储层在不同含水饱和度条件时的储量采出程度，揭示了井网加密对提高储量采出程度作用，以采出程度提高5%~10%和大于10%为依据，建立井网加密可行性判识图表，为气藏井网部署和加密方案优化提供了参考依据。实验岩心常规空气渗透率分别为1.63×10^-3μm²、0.58×10^-3μm²、0.175×10^-3μm²、0.063×10^-3μm²，含水饱和度介于30.3%~71.1%之间。研究结果表明：渗透率为1.63×10^-3μm²的储层，采出程度总体均较高，除了在含水饱和度高达69.9%时的采出程度与井控范围有关外，其余含水饱和度条件下，采出程度与井控范围关系不大，可以采用大井距开发；渗透率为0.58×10^-3μm²的储层，采出程度与含水饱和度和井控范围关系密切，随含水饱和度降低、井控范围加密而增加；渗透率为0.175×10^-3μm²的储层，采出程度受含水饱和度的影响十分显著，只有在含水饱和度≤52.3%时，井网加密优化可提高储量采出程度，当含水饱和度>52.3%时，储量采出程度均较低，一般≤10%，即使井控范围加密至100 m，也难以得到提高；渗透率为0.063×10^-3μm²的储层，总体上采出程度非常低，即使含水饱和度仅有31.6%，井控范围加密至100 m，其采出程度最高也只有2.3%，因此，该类储层依靠井网加密难以得到有效动用。

The reserve producing degree of sandstone reservoirs with different permeability under different water saturation conditions has been systematically studied by combining physical simulation experiment with mathe-matical evaluation method during well control range from 500 m to 100 m (the equivalent of well spacing from 1 000 m to 200 m). This paper reveals the effect of well pattern infilling on increasing reserve producing degree，and the chart for identifying the feasibility of well pattern infilling has been established based on the increase of the recovery degree by 5%-10% and more than 10%,which provides a reference for the well pattern disposetion and infilling scheme optimization of gas reservoirs. The core with conventional air permeability of 1.63×10^-3 μm²，0.58×10^-3 μm²，0.175×10^-3 μm² and 0.063×10^-3 μm² and the water saturation between 30.3% and 71.1% has been used in the experiments. The results show that the reservoir with permeability of 1.63×10^-3 μm² has a high degree of production. Except when the water saturation is as high as 69.9%, the production degree is related to the well control range, the production degree has little relation with well control range, and it can be developed with large well spacing. For reservoirs with permeability of 0.58×10^-3 μm², the degree of production is closely related to water saturation and well control range，and it increases with the decrease of water saturation and the densification of well control range. For reservoirs with permeability of 0.175×10^-3 μm²，only when the water saturation is less than or equal to 52.3%, well pattern infilling optimization can improve the degree of reserve production, and when the water saturation is more than 52.3%，the degree of reserve production is low, usually less than or equal to 10%. Even if the well control range is encrypted to 100m，it is difficult to improve. For the reservoir with a permeability of 0.063×10^-3 μm², it has a very low degree of production as a whole，even if the water saturation is only 31.6% and the well control range is infilled to 100m，the highest degree of production is only 2.3%，therefore it is difficult to improve by well pattern infilling for this kind of reservoir.

致密砂岩气藏储层物性特征差异性较大，其不确定性严重制约气藏的稳产和高效开发。为有效开发致密砂岩气藏未动用储量，提高气田产量和采收率，对储层条件较为复杂的致密砂岩气藏进行井网密度优化是必要的。通过分析渗透率、孔隙度、有效厚度、含水饱和度、阈压梯度、产能系数和储容系数这7项储层物性参数对单井动态控制面积的影响，运用模糊数学方法，推理出井间无干扰时储层物性参数与单井动态控制面积的关系；并将计算所得的单井动态控制面积模糊预测值与地质井控面积对比，判断出不同储层物性条件下井网加密后井间是否会产生干扰，得到了随井网密度变化的干扰概率曲线，进而结合井间干扰概率构建了采收率评价模型，并在苏里格气田苏6区块开展应用。结果表明：使用新评价方法计算的致密砂岩气藏单井平均累计产气量及采收率，都与实际区块生产动态结果相一致，证明该方法是合理可靠的。采收率评价新方法为致密砂岩气藏井网优化提供了新思路。

Tight sandstone gas reservoirs have large differences in physical properties and their uncertainty seriously restricts the stable production and efficient development of gas reservoirs. In order to effectively develop the unutilized reserves of tight sandstone gas reservoirs and improve gas production and recovery, it is necessary to optimize well pattern density of tight sandstone gas reservoirs with complex reservoir conditions. By analyzing the effects of seven reservoir physical parameters on single well dynamic control area, including permeability, porosity, effective thickness, water saturation, threshold pressure gradient, productivity coefficient and storage capacity coefficient, the relationship between reservoir physical parameters and single well dynamic control area without interference between wells is inferred by using fuzzy mathematics method. The calculated fuzzy prediction value of the single well dynamic control area is compared with the geological well control area to determine whether there will be interference between wells after the well pattern is encrypted under different reservoir physical conditions, and the interference probability curve that changes with the well pattern density is obtained. Furthermore, a recovery evaluation model is constructed based on the inter-well interference probability, which is applied in Su 6 well area. The results show that using the new evaluation method for tight sandstone gas reservoirs, the average cumulative gas production per well and recovery evaluated through the physical properties of the reservoir are consistent with the actual production dynamics results. Under certain conditions, this method is reasonable and reliable. The new method of recovery evaluation provides new ideas for well pattern optimization of tight sandstone gas reservoirs.

以致密气采收率影响因素及储集层地质特征分析为基础,从剩余气成因角度对苏里格气田已开发区致密气剩余储量进行分类,估算不同类型剩余气储量,并提出相应提高采收率技术对策。苏里格气田致密气剩余储量可划分为4类：井网未控制型、水平井漏失型、射孔不完善型和复合砂体内阻流带型,其中,井网未控制型和复合砂体内阻流带型井间未动用剩余气是气田挖潜提高采收率的主体,井网加密调整是主要手段。综合考虑储集层地质特征、生产动态响应和经济效益要求,建立定量地质模型法、动态泄气范围法、产量干扰率法、经济技术指标评价法4种直井井网加密技术,以及直井与水平井联合井网优化设计方法,论证气田富集区在现有经济技术条件下,合理井网密度为4口/km²,可将采收率由当前的32%提高到50%左右。同时针对层间未动用型剩余储量形成老井挖潜、新井工艺技术优化、合理生产制度优化、排水采气、降低废弃产量5种提高采收率配套技术,可在井网加密的基础上再提高采收率5%左右。研究成果为苏里格气田230×10⁸ m³/a规模长期稳产及长庆气区上产提供了有效的支撑。图6表4参31

提高采收率是中国低渗-致密气田稳产期间面临的核心问题，确定合理的加密井网是提高储量动用程度的关键。通过明确苏里格气田有效储层规模尺度与4种空间组合类型，评价指出气田动静储量比仅为15.3%，储量动用程度低剩余储量规模大，划分出直井未动用、水平井遗留和井间剩余3种剩余储量类型。提出了井网加密是提高井间剩余储量动用程度的有效措施，构建了采收率、采收率增量、平均气井产量、加密井增产气量、产量干扰率等井网加密评价指标体系，确立了合理加密井网需满足的标准。结合地质模型、数值模拟、密井网试验数据验证等手段综合评价认为，合理加密井网应与有效储层组合类型相匹配、与气价及成本条件密切相关。在目前气价波动范围及经济技术条件下，苏里格气田采用4口/km²的加密井网是合理的。

Enhancing oil recovery is an essential issue during the stable production of low-permeability tight sandstone gasfields in China, and the reasonable infilled well pattern is determined as the key to improve reserve producing degree. The effective reservoir scale and four types of space assemblage are identified, and the assessment indicates that the ratio between dynamic and static geological reserves (RDS)is only 15.3% in Sulige gasfield. The reserve producing degree is very low, while the residual reserve scale is large, divided into vertical-well unemployed reserve, horizontal-well remaining reserve and inter-well residual reserve. It is proposed that well pattern infilling is an effective measure to improve inter-well residual reserve, and the evaluation index system is constructed including recovery ratio, recovery increment, average gas well production, increased gas production of infilled well and production interference ratio. Meanwhile, the standard for reasonable infilled well pattern is also determined. Through geologic model, numerical simulation, test data verification of dense well pattern and other means, it is comprehensively concluded that the reasonable infilled well pattern is matched with effective reservoir assemblage type and closely related to natural gas price and relevant cost. In current gas price fluctuation range and economic-technological conditions, the infilled well pattern of 4 wells/km² is reasonable.

针对我国典型的低渗致密砂岩气藏，通过大量岩心实验和露头剖面精细取心测试分析，研究了应力作用对储层渗透率的影响、储层非均质性以及储层含水饱和度等特征，选用有代表性的岩心，开展了系统的单相气体渗流，含水条件下的气相渗流以及气、水两相渗流实验，分析了低渗致密砂岩储层单相气体渗流形态，含水饱和度变化对气相渗流能力的影响以及气、水两相渗流特征；在此基础上，采用气藏开发物理模拟实验技术，模拟研究了气藏衰竭开采过程中储层渗透率、含水条件、配产与废弃条件、纵向储层渗透率差异、平面非均质(储层砂体间存在阻流带)等多种因素对低渗致密砂岩气藏采收率的影响，根据权重分析对这5类影响因素进行了排序，结果表明储层物性和储层含水饱和度对采收率的影响最大，权重分别占到0.24和0.38，为进一步提高气藏采收率奠定了基础。

The effect of stress on the reservoir permeability and the features of reservoir heterogeneity and formation water saturation were analyzed by means of a huge number of core experiments and test analyses of outcrop section fine coring in the typical low permeability tight sandstone gas reservoirs.With some representative samples,we analyzed the single-phase gas seepage state of low permeability sandstone reservoir,the impact of water saturation on gas permeability and gas water two phase percolation characteristics by conducting systematically single-phase gas seepage experiments,gas percolation experiments under aquiferous condition and seepage tests of gas-water two-phase.On this basis,we studied the impact of various factors such as reservoir permeability,aquiferous conditions,proration and abandoned conditions,longitudinal reservoir permeability differences and the lateral heterogeneity-blocking zone between reservoir sand bodies on the recovery efficiency of low permeability tight sandstone gas reservoir in the process of depletion-drive development by using the physical simulation experimental techniques for gas reservoir development.Then,these five kinds of factors were sorted according to the weight analysis.The results show that reservoir property and reservoir water saturation have the largest effect on the recovery efficiency,whose weight accounted for 0.24 and 0.38,respectively.This study laid a solid foundation for further improving gas reservoir recovery efficiency.

苏里格致密砂岩气田储层物性差、垂向上发育多层透镜状有效砂体、规模小、非均质性强，现有井网对储层控制不足，采收率偏低。井网优化调整是致密气提高储量动用程度及采收率的最有效手段之一。根据储层结构及气井生产开发效果，将气田可效益动用储层划分为3种类型，分别对应储量丰度为：>1.8×10⁸m³/km²、（1.3~1.8）×10⁸m³/km²、（1.0~1.3）×10⁸m³/km²。基于不同储层条件下的密井网试验区实际生产数据，结合储层规模分析和气井泄气范围评价，兼顾开发效益和提高采收率，从采收率增幅拐点、区块整体有效、新井能够自保等方面开展适宜井网密度综合分析，明确了3类储层的适宜井网密度分别为3口/km²、4口/km²、4口/km²。苏里格致密砂岩气田剩余可动储量1.23×10¹²m³，新的差异化布井方式相比于600 m×800 m井网，可多钻井1.2万口，多建产能450×10⁸m³，累计多产气2 000×10⁸m³，可将采收率由32%提升至48.5%。

Sulige tight sandstone gas field is characterized by poor reservoir physical properties, multi-layer lenticular reservoir structure, small scaled sand bodies and strong heterogeneity. That the existing well pattern has insufficient reservoir control results in low recovery factor. At present, the well pattern infilling adjustment is one of the most effective means to enhance the recovery factor. According to reservoir structure and gas well production effect, the recoverable reservoirs of the gas field can be divided into three types, corresponding to the reserves abundance of>1.8×10⁸ m³/km²， （1.3-1.8）×10⁸ m³/km²，（1.0-1.3）×10⁸ m³/km². Based on the production data of dense well pattern test area under different reservoir conditions, combined with analysis of reservoir scale and scope of gas well deflating evaluation, combining development efficiency and recovery factor enhancement, the suitable well spacing density comprehensive analysis was carried out from the perspectives of inflection point of recovery factor enhancement, overall development effectiveness of the well groups, and the break-even point of the infilling well. It is determined that the suitable well pattern density for type I, II and III reservoirs is 3, 4, and 4 wells/km², respectively. The scale of remained producing reserves of the gas field is 1.23 trillion cubic meters. If new well pattern is deployed there, compared with the 600 m×800 m well pattern, 12 000 more wells can be drilled, additional 45 billion cubic meters producing capacity can be built, another 200 billion cubic meters of gas will be produced. Then, the recovery factor will rise from 32% to 48.5%.

基于四川盆地海相大中型气田基本特征分析,结合海相克拉通阶段主要成藏地质单元划分及其对关键成藏要素的控制作用研究,探讨盆地海相碳酸盐岩大中型气田分布规律,指出勘探方向。通过周期性拉张-隆升背景的分析,提出四川海相克拉通阶段发育形成了5个大型古裂陷、3个大型古隆起、5个大型古侵蚀面等大型地质单元,这些地质单元控制了大中型气田的关键成藏要素：①大型古裂陷控制了优质烃源岩生烃中心展布;②大型古裂陷边缘、古隆起高部位、古侵蚀面控制了优质储集层的展布;③大型古裂陷、古隆起、古侵蚀面和现今构造背景联合控制了多类大中型圈闭的形成;④大型地质单元内圈闭继承性演化控制天然气规模聚集。通过大中型气田展布特征与大型成藏地质单元的对比分析,提出单个或多个成藏地质单元与现今构造的叠合关系控制了大中型气田的分布,“三古”叠合区最为有利。德阳—安岳古裂陷周缘、龙门山古裂陷东缘、开江—梁平海槽及城口—鄂西海槽边缘带、环川中水下古隆起高部位、川东—蜀南地区茅口组顶界古侵蚀面、川中—川西雷口坡组顶界古侵蚀面等,是四川盆地海相碳酸盐岩大中型气田勘探主要领域和方向。图6表2参59

Based on the analysis of the basic characteristics of medium- and large-sized marine gas fields in Sichuan Basin, combined with the division of major reservoir forming geological units in the marine craton stage and their control on key hydrocarbon accumulation factors, the distribution law of medium- and large-sized marine carbonate gas fields in the basin was examined and the exploration direction was pointed out. Through the analysis of the periodic stretching-uplifting background, it is concluded that five large scale paleo-rifts, three large scale paleo-uplifts, five large scale paleo erosion surfaces were formed in the marine craton stage of Sichuan Basin, and these geological units control the key reservoir forming factors of medium and large sized gas fields: (1) Large-scale paleo-rifts control the distribution of high-quality hydrocarbon generation centers. (2) The margin of large-scale paleo-rifts, high position of paleo-uplifts and paleo erosion surfaces control the distribution of high-quality reservoirs. (3) Large-scale paleo-rifts, paleo-uplifts, paleo erosion surfaces and present tectonic setting jointly control the formation of many types of large and medium-sized traps. (4) Natural gas accumulation is controlled by the inheritance evolution of traps in large geological units. Based on the comparative analysis of the distribution characteristics of medium- and large-sized gas fields and large geological units, it is proposed that the superimposition relationship between single or multiple geological units and the present structure controls the distribution of medium- and large-sized gas fields, and the "three paleo" superimposed area is the most advantageous. According to the above rules, the main exploration fields and directions of medium- and large-sized marine carbonate gas fields in Sichuan Basin include periphery of Deyang-Anyue paleo-rift, eastern margin of Longmenshan paleo-rift, margins of Kaijiang-Liangping oceanic trough and Chengkou-western Hubei oceanic trough, the high part of the subaqueous paleo-uplifts around Central Sichuan, paleo erosion surfaces of the top boundary of Maokou Formation in eastern and southern Sichuan Basin, paleo erosion surfaces of the top boundary of the Leikoupo Formation in central and western Sichuan Basin.

基于川中古隆起北斜坡震旦系—寒武系天然气藏特征、油气充注史及成藏地质条件分析,研究其天然气成因、成藏演化、聚集模式及大型岩性气藏形成条件。通过天然气组成、碳氢同位素组成、流体包裹体、储集层沥青、岩相古地理及滩体刻画等综合分析,认为：①北斜坡震旦系—寒武系天然气主要为原油裂解气,多套烃源岩贡献比例不同导致不同层系天然气地球化学特征差异。②北斜坡震旦系、寒武系气藏均为单斜背景下的岩性气藏,前者为常压,后者为高压;发育单源下生上储,双源下生上储、旁生侧储,双源下生上储、上生下储3类生储盖组合;二叠纪—三叠纪是原油主要生成期,早—中侏罗世是原油裂解气及湿气主要生成期,晚侏罗世—白垩纪是干气主要生成期。③北斜坡震旦系—寒武系大型岩性气藏形成的条件主要是斜坡背景下大面积分布的规模滩相储集体邻近源岩或处于古油藏范围,规模丘滩体储集层与滩间致密带封隔层有效匹配形成大型岩性圈闭,有利于近源聚集和古油藏裂解气“原位”规模聚集成藏。研究和勘探成果证实北斜坡发育多层系大型岩性气藏,天然气资源规模超过万亿立方米,勘探潜力大。

选取四川盆地高石梯—磨溪区块基质孔隙型、裂缝型、溶蚀孔洞型3类储集层全直径岩心,开展高温、高压条件下的气、水两相相对渗透率测试,分析气水相渗曲线特征及气井流入动态。将实验数据归一化处理后形成了3类储集层的气、水相对渗透率曲线标准图版;针对裂缝型储集层的渗流特点,提出气、水两相相对渗透率曲线校正方法并对相应图版进行校正;运用标准图版计算研究区不同类型储集层气水两相流入动态曲线（IPR）,并通过实际井的动态进行验证。研究区储集层相对渗透率曲线等渗点含水饱和度高达70%以上,具有强亲水特征,气水共渗区间、气驱水效率以溶蚀孔洞型最大,基质孔隙型次之,裂缝型最小;岩心渗透率的恢复程度以裂缝型最大,溶蚀孔洞型次之,基质孔隙型最小。校正后的裂缝型碳酸盐岩储集层气、水相渗曲线能更好反映实际气藏的气水两相渗流规律,标准图版可用于各类气藏工程计算;计算的IPR曲线,其特征与实际生产井动态相符,可用于实际气井配产与生产动态分析。图11表4参19

Gas-water relative permeability was tested in the full diameter cores of three types of reservoirs (matrix pore, fracture and solution pore) in Gaoshiti-Moxi block under high pressure and temperature to analyze features of their gas-water relative permeability curves and gas well inflow dynamics. The standard plates of gas-water two-phase relative permeability curves of these types reservoirs were formed after normalization of experimental data. Based on the seepage characteristics of fractured reservoirs, the calibration methods of gas-water two-phase relative permeability curves were proposed and the corresponding plates were corrected. The gas-water two-phase IPR (inflow performance relationship) curves in different type reservoirs were calculated using the standard plates and validated by the actual performances of gas wells respectively. The results show that: water saturations at gas-water relative permeability equal points of studied reservoirs are over 70%, indicating strong hydrophilic; the dissolved cave type has the biggest gas-water infiltration interval and efficiency of water displacement by gas, followed by the matrix pore type and then fractured type; and the fractured type has the highest the permeability recovery degree, followed by the dissolved cave type and then matrix pore type. The calibrated gas-water two-phase relative permeability curves of fractured carbonate reservoirs can better reflect the gas-water two-phase seepage law of actual gas reservoirs and the standard plates can be used in the engineering calculation of various gas reservoirs. The characteristics of calculated IPR curves are consistent with the performance of actual producing wells, and are adaptable to guide production proration and performance analysis of gas wells.

围绕非均匀水侵导致裂缝—孔隙型气藏采收率低这一共性难题，以典型气藏地质模型为基础，研发大型二维物理模拟模型，建立裂缝—孔隙型气藏大型物理模拟实验方法及其装置，开展了气藏水侵规律及对采收率影响和排采优化提高气藏采收率物理模拟实验，研究了水体倍数、配产高低对气藏水侵规律及采收率的影响，探索了排水时机、排水规模、排水方式等对提高气藏采收率的作用。结果表明：①作用于单井的水体倍数和气井配产高低对水侵前缘推进速度、水侵波及特征以及气藏采收率影响均十分显著，开发过程中应合理部署井网和控制气藏采气速度从而降低水侵伤害程度；②排水时机、排水规模、排水方式等技术措施对提高气藏采收率效果影响显著，应根据气藏实际条件制订合理的优化方案。研究成果对类似气藏制订控水开发提高采收率技术对策具有指导意义。

This paper focuses on the common problem of low recovery of fractured-porous gas reservoirs due to water invasion， develops a large-scale planar physical simulation model based on a typical gas reservoir geological model， and establishes a large-scale physical simulation experiment method and device for fractured-porous gas reservoirs. Physical simulation experiments on drainage optimization were carried out to enhance gas recovery， and the effects of aquifer size and gas production rate on the water invasion behavior and recovery of gas reservoirs were studied. The effect of drainage timing， drainage volume， and drainage method was explored. The results show that： （1） The water energy acting on a single well and the gas production rate have significant effects on the advancement velocity of the water invasion front， the characteristics of water invasion， and the gas reservoir recovery. The deployment of the well network and the recovery rate should be optimized to reduce the water invasion damage during the development process. （2） The technical measures such as drainage timing， drainage volume， and drainage method have significant effects on enhancing gas recovery， and reasonable optimization plans should be reformulated according to the actual conditions of gas reservoirs. The results of the study are useful for formulating technical schemes for similar reservoirs to enhance gas recovery.

针对裂缝—孔隙型气藏水侵规律及影响气藏采出程度机理的认识难题，采用物理模拟实验技术，开展了贯通水平裂缝条件下的水侵规律实验、储层基质渗吸水实验以及储层基质渗吸水后对储层供气机理的影响实验，明确了储层基质水侵与裂缝水侵的区别，认识了裂缝—孔隙型边底水气藏水侵规律及其对气藏产能以及采收率的影响机理，即裂缝水侵过程中边底水会沿裂缝快速突进、同时储层基质会渗吸水、基质渗吸水后减少气相渗流通道，从而增加储层基质气相渗流阻力，降低气藏稳产能力和最终采出程度，该项机理认识揭示了裂缝气藏水侵后导致气井产量、最终采出程度大幅度下降的主要原因。在上述机理认识基础上，进一步研究了贯通裂缝水侵前沿推进速度与储层物性、水体大小的关系，分类测试了不同渗透率储层基质渗吸水的能力，模拟评价了不同渗吸水方式和渗吸水量对气藏储层稳产能力和最终采出程度的影响，研究成果可以为我国塔里木盆地迪那气田、克深气田以及四川盆地磨溪龙王庙气藏科学开发提供技术支持。

Aimed at water invasion law in fracture-pore gas reservoir and influencing factors of recovery percent of gas reservoir,the physical simulation experiment technique was used in the water invasion law experiment of horizontal cut-through fracture,the water imbibition experiment of matrix rock and its impacts on the formation gas supply mechanism experiment.In the paper,difference between the water invasion in matrix rock and fracture is determined.The water invasion law and the influence mechanism of water invasion on gas reservoir productivity and recovery efficiency in fracture-pore edge-bottom water gas reservoir was acquired.In the process of the water invasion into the fractured gas reservoir,while the water is invading into the fracture fast,the water is imbibing into the matrix rock which will result in reduction of gas phase percolation roads,increase of the gas phase percolation resistance of matrix rock and reduction of gas reservoir productivity and ultimate recovery percent of gas reservoir.The knowledge revealed the reduction causes of the gas well productivity and the recovery ratio of gas reservoir after water invasion into the fractured gas reservoir.Based on the above knowledge,the relation of water encroachment frontier advance rate and formation physical property,water body size was studied further.The different permeability matrix rock imbibition capacity was tested.The influence of water imbibition style and imbibition volume on the stable yield and ultimate recovery percent of reserves is evaluated.The study achievements can provide technical support for the development of Dina and Keshen gas reservoir of Tarim Basin and Longwangmiao gas reservoirs in the Moxi block of Sichuan Basin.