空气钻井条件下中子孔隙度测井响应的蒙特卡罗模拟

空气钻井作为一种欠平衡钻井技术,会对中子孔隙度测井产生不同的影响。利用蒙特卡罗方法建立裸眼井的中子孔隙度计算模型,模拟空气钻井时不同孔隙度、岩性、泥质含量、井眼尺寸、井筒空气压力条件下的中子输运过程,研究热中子计数比值与孔隙度的关系。认为空气钻井时远近探测器的热中子计数都随孔隙度的增加而增加,然后再缓慢减少;石灰岩地层的热中子计数率比值高于砂岩,泥质含量越高的地层热中子计数率比值越大;井眼尺寸对热中子计数率比值影响很大,孔隙度越大的地层井眼尺寸影响越大,且井眼尺寸越大,比值变化越小,越不利于中子孔隙度的确定;井筒空气的压力大小对热中子计数率比值影响很小。因此空气钻井时必须重新刻度中子孔隙度,并对岩性、泥质含量、井眼尺寸等因素进行校正。     

中子和密度测井找气方法的更新

中子和密度测井在复杂岩性地层中找气,如果只用中子和密度孔隙度差异性质指示气层,由于复杂岩性的干扰,容易出现多解性。本文建立的测井找气模型、刻度公式、气层下限值、指示和验证气层法则,更新了中子和密度测并找气方法,能够压制复杂岩性的干扰,排除多解性。文中给出的测井找气实例表明,采用更新后的测井找气方法指示低孔隙度复杂岩性气层,提高了中子和密度测井指示气层的分辨率、直观性和准确性,从而获得了更好的找气效果。     

双密度重叠找气新方法

本文根据岩石孔隙中的天然气引起介电测井孔隙度减小和密度测井孔隙度增大的原理,建立了双密度重叠找气新方法,消除了岩性的影响,提高了测井找气的分辨率,增加了评价气层的直观性。该方法用于寻找陕甘宁盆地低孔隙白云岩气藏,获得了明显的地质效果。这种方法还可以在其它储层岩性气藏中应用。     

浅谈煤层气与游离气共同开发新思路

游离气是由煤系地层生成的烃类气体,游离于储层储集空间之中而形成天然气气藏,与煤层中的吸附气呈共生关系.根据游离气储集层的岩性及空间组合特征,可将其分为3种类型:煤岩顶板砂岩型、煤岩顶板灰岩型、不整合面灰岩型.测井中子密度重叠法是判别煤系地层游离气层主要的方法之一,拉梅常数、剪切模量及密度预测法可有效识别砂岩中的气饱和层.AVO高异常可准确解释煤层气的富集部位,等温曲线法及补偿中子变化量法能够有效计算煤层气的含气量.游离气与煤层气的成藏特点使得煤层气与游离气共同开发成为可能.以山西沁水盆地为例,介绍了在查明煤层气和游离气富集高产部位后,利用高密度勘探开发井网,有望实现煤层气与煤系地层浅层游离气的联合开发.     

基于主成分分析的致密砂砾岩孔隙度测井评价方法

岩性识别是致密砂砾岩测井评价的重要工作。砂砾岩岩性多样、成分复杂,导致测井识别岩性准确率低、测井解释孔隙度不准确。以东营凹陷北部陡坡带沙四下亚段致密砂砾岩为例,在对其岩石学特征分析的基础上,按照岩石类型和骨架矿物差异给砂砾岩分类,利用铸体薄片资料对测井曲线进行岩性标定,提取各种岩性的测井响应特征,在此基础上建立了基于主成分分析的测井岩性识别方法,并分岩性建立了孔隙度测井评价模型,提高了砂砾岩测井岩性识别和测井孔隙度计算的准确率。     

含泥质灰岩储层的测井流体识别——以中东YL-DS油田为例

中东YL-DS油田高含泥质灰岩储层(泥质含量3%~8%)电阻率低,常规解释的含水饱和度较高,按纯灰岩储层段流体评价标准常被判定为水层。本研究避开对难以量化表征的纯灰岩骨架中束缚水的直接求取,通过计算储层中的泥质束缚水孔隙度来直接校正常规含水饱和度,简单易行,在实践中取得了良好的效果。具体方法为:根据纯泥岩的简化模型计算纯泥岩孔隙度,然后采用能谱测井资料计算干黏土的密度值,计算泥质灰岩储层中的泥质束缚水孔隙度,对常规阿尔奇公式计算的水饱和度进行泥质束缚水饱和度校正而获得视纯灰岩含水饱和度,最后采用校正后的含水饱和度和纯灰岩段标准解释图版综合判断储层流体性质。     

中子测井资料的地质应用

在统计分析了大量的中子测井资料和实验室测试的各种煤、岩性质数据的基础上,应用回归分析、体积模型等数学方法,论述了中子测井资料在计算岩石孔隙度、岩石抗压强度、布氏硬度系数、地层声阻抗参数、岩性组分和岩石粒度方面的地质应用效果。      

地层水矿化度对补偿中子测井影响的自动校正方法研究

在以往补偿中子测井的蒙特卡罗模拟研究中,地层水矿化度多设置为0,但实际上地层水矿化度变化会对补偿中子测井造成影响。对此文中利用蒙特卡罗方法模拟研究了地层水矿化度对补偿中子测井的影响并提出其校正方法。先后模拟计算了不同孔隙度条件下,矿化度与计数率、计数比的关系以及矿化度对计数比与孔隙度的关系和孔隙度灵敏度的影响。结果表明,在相同孔隙度条件下,探测器计数率随矿化度增加而降低,远探测器计数率降低速率大于近探测器;近远计数比随矿化度增加呈二次函数线性增加;基于大量模拟数据,建立了适用于不同地层水矿化度条件下孔隙度与矿化度的双变量函数关系式,消除了地层水矿化度对补偿中子测井的影响。此外,孔隙度灵敏度在中、低孔隙度地层受矿化度影响明显。文中建立的孔隙度与矿化度的双变量函数关系式,完成了地层水矿化度效应的自动校正,简化了与地层水矿化度效应相关的后续校正工作,避免了复杂的仪器重新刻度,为准确评价储层孔隙度提供了理论依据。     

利用测井资料分析成岩作用对储集层的影响

应用测井资料进行压实作用、孔隙演化、裂缝、矿物成分详尽分析基础上 ,结合成岩作用各个阶段对储集层性能影响的研究 ,讨论了应用测井资料分析成岩作用对储集层影响的物理基础 ,进而指出应用测井资料分析成岩作用不同阶段对储集层影响的可行性。方法为 :(1 )成岩作用早期 :应用孔隙度测井和岩性测井资料 ,通过压实曲线分析压实作用区间 ;(2 )成岩作用中期 :首先根据孔隙度测井资料分析声波孔隙度、密度 -中子测井孔隙度 ,分析次生孔隙 ,并应用交会图技术 ,确定矿物成分 ,分析胶结、交代作用形式和强度 ,然后根据泥质指示测井确定泥质含量 ,进一步利用自然伽玛能谱测井 ,尤其是Th、K含量分析粘土矿物 ;(3)成岩作用晚期 :进行次生孔隙、裂缝、颗粒成分与含量、粘土矿物分布规律研究。以上分析方法经吐哈盆地实际资料验证 ,效果良好     

岩性约束反演方法及应用

本文采用非线性反演技术建立了岩性约束反演计算方法，用于地层岩性解释和储层模拟、描述等方面。文中讨论了岩性正演数学模型的建立、初始模型的选取和约束条件对反演结果的影响。给出了综合利用地震、测井和地质资料计算孔隙度和泥质含量的反演结果，并分析了反演精度。理论模型计算结果说明了岩性约束反演的可行性和正确性。并给出Ｓｕｎ工作站上应用该软件处理某油田实际资料的岩性反演结果。     

Petrophysical parameters and modelling of the Eocene reservoirs in the Qadirpur area,Central Indus Basin,Pakistan: implications from well log analysis

The Eocene rock units of the Qadirpur field, Central Indus Basin (Pakistan), are investigated petrophysically for their detailed reservoir characterization. The different petrophysical parameters determined include the following: true resistivity, shale volume, total porosity, effective porosity, density and neutron porosity, water and hydrocarbon saturation, bulk volume of water, lithology, gas effect, P-wave velocity, movable hydrocarbon index and irreducible water saturation and integrated with different cross-plots. The Eocene reservoirs are excellent with high effective porosity (2–32 %) and hydrocarbon saturation (10–93 %). Among these, the Sui Upper Limestone is an overall a poor reservoir; however, it has some hydrocarbon-rich intervals with high effective porosity and better net pay. All the net pay zones identified show low and variable shale volume (5–30 %). The secondary porosity has added to the total and effective porosities in these reservoirs. The main contributors to the porosity are the chalky, intercrystalline and vuggy/fracture types. The thickness of the reservoirs zones ranges from 4.5 to 62 m. These reservoirs are gas-producing carbonates with almost irreducible water saturation (0.002–0.01) and are likely to produce water-free hydrocarbons. The lower values of moveable hydrocarbon index (0.07–0.9) show that the hydrocarbons are moveable spontaneously to the well bore. The proposed correlation model shows that the reservoirs have an inclined geometry and are a part of an anticlinal trap.     

Beyond dual-porosity modeling for the simulation of complex flow mechanisms in shale reservoirs

The state of the art of modeling fluid flow in shale reservoirs is dominated by dual-porosity models which divide the reservoirs into matrix blocks that significantly contribute to fluid storage and fracture networks which principally control flow capacity. However, recent extensive microscopic studies reveal that there exist massive micro- and nano-pore systems in shale matrices. Because of this, the actual flow mechanisms in shale reservoirs are considerably more complex than can be simulated by the conventional dual-porosity models and Darcy’s law. Therefore, a model capturing multiple pore scales and flow can provide a better understanding of the complex flow mechanisms occurring in these reservoirs. This paper presents a micro-scale multiple-porosity model for fluid flow in shale reservoirs by capturing the dynamics occurring in three porosity systems: inorganic matter, organic matter (mainly kerogen), and natural fractures. Inorganic and organic portions of shale matrix are treated as sub-blocks with different attributes, such as wettability and pore structures. In kerogen, gas desorption and diffusion are the dominant physics. Since the flow regimes are sensitive to pore size, the effects of nano-pores and micro-pores in kerogen are incorporated into the simulator. The multiple-porosity model is built upon a unique tool for simulating general multiple-porosity systems in which several porosity systems may be tied to each other through arbitrary connectivities. This new model allows us to better understand complex flow mechanisms and eventually is extended into the reservoir scale through upscaling techniques. Sensitivity studies on the contributions of the different flow mechanisms and kerogen properties give some insight as to their importance. Results also include a comparison of the conventional dual-porosity treatment and show that significant differences in fluid distributions and dynamics are obtained with the improved multiple-porosity simulation.     

Probability distribution method based on the triple porosity model to identify the fluid properties of the volcanic reservoir in the Wangfu fault depression by well log

Due to the powerful anisotropy of the physical properties of volcanic reservoirs, their component minerals and pore configuration are very complex, rendering fluid identification very difficult. This paper first computed the cementation exponent, which was based on triple porosity model, then used the varied matrix density and matrix neutron to compute the porosity, and finally combined with resistivity well log, and a P ^1/2 probability distribution curve was built. The fluid properties were predicted from the shape of the P ^1/2 probability distribution curve. Good results were achieved when these methods were used in the volcanic reservoir of the Wangfu fault depression, which indicated that these methods can be used in the fluid property identification of volcanic reservoirs and can also be referred to for other lithology reservoirs.     

多元回归分析方法在火山碎屑岩储层孔隙度计算中应用

火山碎屑岩储层具有岩性复杂、测井数据种类繁多以及区域大、层位多等特点,导致火山碎屑岩储层测井参数难于确定。以海拉尔盆地乌尔逊--贝尔凹陷的火山碎屑岩储层为研究主体,在准确识别岩性的基础上,对测井资料进行预处理,根据岩心分析资料计算其理论骨架参数值。依据孔隙度与中子、密度、声波三者之间的关系,将多元回归方法应用在孔隙度计算中,实现利用多元回归方法计算火山碎屑岩储层孔隙度。其结果与岩心分析孔隙度比较接近,绝对误差仅为1. 6%,能满足储量计算要求。     

Well log data analysis for lithology and fluid identification in Krishna-Godavari Basin,India

Well log analysis provides the information on petrophysical properties of reservoir rock and its fluid content. The present study depicts interpretation of well log responses such as gamma ray, resistivity, density and neutron logs from six wells, namely W-1, W-2, W-9, W-12, W-13 and W-14 under the study area of Krishna-Godavari (K-G) basin. The logs have been used primarily for identification of lithology and hydrocarbon-bearing zones. The gamma ray log trend indicates deposition of cleaning upward sediment. Coarsening upward, clayey-silty-sandy bodies have been evidenced from the gamma ray log. Gas-bearing zones are characterised by low gamma ray, high deep resistivity and crossover between neutron and density logs. Total 14 numbers of hydrocarbon-bearing zones are identified from wells W-9, W-12, W-13 and W-14 using conventional log analysis. Crossplotting techniques are adopted for identification of lithology and fluid type using log responses. Crossplots, namely P-impedance vs. S-impedance, P-impedance vs. ratio of P-wave and S-wave velocities (Vp/Vs) and lambda-mu-rho (LMR), have been analysed to discriminate between lithology and fluid types. Vp/Vs vs. P-impedance crossplot is able to detect gas sand, brine sand and shale whereas P-impedance vs. S-impedance crossplot detects shale and sand trends only. LMR technique, i.e. λρ vs. μρ crossplot is able to discriminate gas sand, brine sand, carbonate and shale. The LMR crossplot improves the detectability and sensitivity of fluid types and carbonate lithology over other crossplotting techniques. Petrophysical parameters like volume of shale, effective porosity and water saturation in the hydrocarbon-bearing zones in these wells range from 5 to 37%, from 11 to 36 and from 10 to 50% respectively. The estimated petrophysical parameters and lithology are validated with limited core samples and cutting samples from five wells under the study area.     

川西拗陷须五段非常规气形成条件分析

随着对非常规气蔵的研究方法和开采手段的升级,使页岩气得以开发。川西拗陷须五段常规的思维是把它作为烃源岩来认识的,运用非常规页岩气的研究理念和方法,针对川西拗陷两条野外剖面(莲花剖面、万家坪剖面)及6口取心井(XYHF-1井,XYHF-2井,X503井,FG5井,GH2井,MY1井)的岩心观察、取样分析测试,以分析川西拗陷须五段具有形成非常规气蔵的条件,并用3种不同的表征方法(激光共聚焦法、高压压汞法、氮气吸附法)对须五段内不同类型的岩石进行孔隙度、渗透率及其连通性时行表征,结果表明:细砂岩中不同类型孔隙的孔隙度为0.41%～6.65%,平均总孔隙度为2.14%;泥(页)岩的孔隙度为1.51%～5.99%,总孔隙度为2.70%。微米CT扫描发现须五段上亚段细砂岩的连通性好于下亚段,中亚段以粉砂岩为主,孔隙连通性差,有机质含量低;泥(页)岩的孔隙连通性也差,孔隙发育依附于有机质的发育,泥(页)岩样品的有机碳含量主要分布在0.5%～3%之间。综合评价认为马井-邡、崇州-郫县、新场-丰谷等地区成蔵条件较好,为I类地区,是川西坳陷须五段页岩气的目标区域。     

青海木里三露天天然气水合物钻孔岩性测井识别

三露天井田具有断层发育、地层缺失和重复明显、岩性种类较多等特点,岩性识别难度较大。为此,专门利用测井资料对三露天井田地层岩性进行了岩性识别研究。通过对14个天然气水合物钻孔不同岩性的测井响应特征分析,优选了自然伽马、中子和密度测井作为岩性识别敏感参数,并采用交会图技术制作了岩性识别图版,建立岩性划分标准,对三露天井田地层岩性进行识别与划分。利用测井资料能够识别7种主要岩性,包括砂岩、粉砂岩、泥质粉砂岩、粉砂质泥岩、泥岩、油页岩和煤等。根据岩性测井识别结果,三露天井田岩性分布特征在横向上表现为东部砂岩物性好,西部地区泥岩较为发育;纵向上表现为木里组地层砂泥比为4.48,含有煤层204.5 m;江仓组地层砂泥比为0.84,泥岩和油页岩较为发育,更有利于水合物赋存。测井岩性识别结果为寻找三露天井田天然气水合物有利储层奠定了基础。     

鄂西地区震旦系陡山沱组二段页岩气储层测井评价初探

鄂西地区震旦系陡山沱组是中国页岩气勘查的新层系,其页岩储层矿物成分以白云石为主,测井响应特征与奥陶系五峰组—志留系龙马溪组、寒武系牛蹄塘组硅质页岩明显不同,原有储层"七性"关系测井评价对于陡山沱组页岩储层精细刻画和压裂施工解释评价存在一定的不适用性。本文以鄂阳页1井为例,综合利用常规测井、特殊测井和样品测试分析资料,研究发现不同于五峰组—龙马溪组和牛蹄塘组硅质页岩"四高四低"测井响应特征,陡山沱组二段云质页岩具有低伽马、低铀、低声波时差、低中子,高电阻率、高密度"四低两高"测井响应特征,认为元素测井是评价陡山沱组二段页岩地层总有机碳含量最直接和有效的方法,MRIL-P型核磁测井适用于该地层孔隙度参数评价。通过拟合计算完善了适用于该地层的含气量估算方法,获取了有利页岩储层评价参数,研究成果将为同类型页岩储层测井评价提供参考依据。     

Production rate analysis of multiple-fractured horizontal wells in shale gas reservoirs by a trilinear flow model

Most multiple-fractured horizontal wells experience long-term linear flow due to the ultralow permeability of shale gas reservoirs. Considering the existence of natural fractures caused by compression and shear stresses during the process of tectonic movement or the expansion of high-pressure gas, a shale gas reservoir can be more appropriately described by dual-porosity medium. Based on the assumption of slab dual-porosity, this paper uses the trilinear flow model to simulate the transient production behavior of multiple-fractured horizontal wells in shale gas reservoirs, which takes the desorption of adsorbed gas, Knudsen diffusion and gas slippage flow in the shale matrix into consideration. Production decline curves are plotted with the Stehfest numerical inversion algorithm, and sensitivity analysis is done to identify the most influential reservoir and hydraulic fracture parameters. It was found that the density and permeability of the natural fracture network are the most important parameters affecting the production dynamics of multiple-fractured horizontal wells in shale gas reservoirs. The higher the density and permeability of the natural fractures are, the shorter the time is required to exploit the same amount of reserve, which means a faster investment payoff period. The analytical model presented in this paper can provide some insight into the reserve evaluation and production prediction for shale gas reservoirs.