泥页岩的X射线衍射定向指数与理化性能及井壁稳定的关系

首次提出了泥页岩X射线衍射定向指数的测定方法,探讨了定向指数与矿物成分,定向指数与泥页岩理化性能（密度、回收率、膨胀率、阳离子交换容量等）的关系。并在定向指数的基础上,提出了综合指数的概念,然后以定向指数和综合指数为主要依据,对坍塌地层泥页岩进行了分类。这对于钻井工程上研究井壁稳定的机理,预防井壁失稳,具有重要的理论意义和实用价值。     

深层泥页岩井壁失稳机理与预测模型研究进展

深层油气资源开发已成为国家油气发展的重要战略，泥页岩井段井壁失稳是制约深层油气资源安全高效开采的技术“瓶颈”。本文在分析深层泥页岩井壁失稳的力学机理和化学机理基础上，着重论述考虑泥页岩水化作用、弱结构面、各向异性和多场耦合的井壁稳定性预测模型的研究进展和发展趋势。钻井液密度不合理是井壁力学失稳的主要原因，泥页岩水化作用是井壁化学失稳的主要原因；在井壁流-固-化-热四场耦合作用下，考虑弱结构面、各向异性对泥浆安全密度窗口的影响，是目前研究深层泥页岩井壁稳定性的主要趋势和方法。     

深部硬脆性泥页岩含水率与强度分布规律研究

泥页岩井壁稳定问题是钻井工程中经常遇到的一个十分复杂且带有世界性的难题。所取岩芯为准噶尔盆地沙窝地区块垮塌严重的深部泥页岩,通过室内试验测定泥页岩不同含水率条件下强度参数（内聚力、内摩擦角、弹性模量、泊松比）值,对试验数据进行回归分析,得出泥页岩含水率与其强度参数的分布规律;并根据渗流力学原理对泥页岩含水率的分布规律做了理论推导。研究结果为计算水化后泥页岩井壁围岩的应力及评价井眼稳定性提供了试验依据和理论基础。     

PPTS-1压力传递型泥页岩渗透性测试系统

井壁失稳一直是困扰油气勘探开发的难题,而泥页岩渗透性是评价泥页岩井壁稳定性的重要指标之一。介绍了一套基于LabVIEW软件平台的PPTS-1压力传递实验系统平台,采用岩心分析法和压力传递测试技术精确测试泥页岩的渗透率。实验结果表明,该实验平台操作简单,性能稳定,测试精度高,为井壁稳定性深入研究提供了支撑。      

中牟页岩气区块泥页岩井壁稳定影响因素分析及技术对策

井壁失稳是钻井过程中常常遇见的难题之一,尤其在钻遇泥页岩井段。针对河南中牟页岩气区块在山西组-太原组泥页岩钻进过程中发生井壁坍塌掉块、卡钻、井径扩大率大等复杂情况,利用MY1井钻井岩心从泥页岩类型划分、孔渗特征、微观结构、岩石力学以及地应力等方面开展井壁稳定性影响因素实验分析。通过分析可知,中牟区块泥页岩属硬脆性泥页岩,造成井壁失稳的主要因素为地层非均质性强,岩石脆性程度较高,微裂缝发育,易导致井壁机械剥落、坍塌掉块。通过合理控制钻井液密度、优化井身结构及钻井参数、研发低自由水强封堵钻井液提高井壁稳定性,在区块钻井实践中取得了较好的应用效果,基本解决了井壁失稳难题。     

泥页岩组构X射线衍射定量分析方法

泥页岩组构意指构成泥页岩的成分单位（分散颗粒、矿物晶体和胶结物等）的空间定向性。首先详细地论述了利用Ｘ射线衍射仪进行泥页岩组构分析的基本原理和实验方法，而后为便于定量地描述泥页岩的组构特征，引入了“定向度”概念并据此把泥页岩组构分成５种类型，进而详细地论述了实际样品分析中的定向度计算方法以及渤海湾盆地黄骅坳陷（大港油田）部分泥页岩样品的计算实例     

横观各向同性水敏性地层斜井眼坍塌压力确定

在以泥页岩为目标储层的非常规油气藏水平井开发中, 钻遇井壁的稳定性问题突出, 一方面是由于在设计钻井液密度时简单采用各向同性介质模型和Mohr-Coulomb强度准则, 另一方面则是由于选用的钻井液性能欠佳, 难以保证建井全过程的井壁稳定。为此, 将地层视为横观各向同性介质, 采用Mogi-Coulomb强度准则判别岩石基体和层理面的稳定性, 同时考虑泥页岩水化作用对岩石力学强度参数的影响, 建立了水敏性地层井壁稳定分析模型, 分析了坍塌压力随井斜、方位、钻井液性能、钻井时间等因素的变化规律。研究结果表明:对于具有显著层理面结构的泥页岩地层, 采用横观各向同性模型比各向同性介质模型更能描述强度的各向异性;采用Mogi-Coulomb准则比Mohr-Coulomb强度准则得到的坍塌压力值与实际吻合程度更高, 在保证井壁稳定的前提下有利于降低钻井液密度, 实现钻井提速;提高钻井液封堵能力、减小泥页岩吸水扩散能力, 有利于延长坍塌周期。利用东濮、威远、焦石坝等工区多口页岩气水平井的实钻资料对本文方法进行了验证, 证实本文方法确定的钻井液密度窗口下值更能满足安全钻井需求。     

煤层气钻井井壁失稳机理及防塌钻井液技术

针对沁水盆地煤层气钻井中存在的井壁稳定技术难题,采用X射线衍射、扫描电镜、泥页岩膨胀实验、页岩分散实验测试了泥页岩和煤岩体的组构及理化性能,分析了井壁失稳机理。依据"多元协同"防塌原理,研选出了高效包被抑制剂、封堵防塌剂和活度平衡剂,构建了泥页岩地层防塌钻井液体系QSFT和煤层钻开液QSMZ。评价结果表明,QSFT体系的粘度、切力适中,滤失量低、泥饼薄,对200 μm裂缝的封堵承压能力达3.0 MPa;QSFT和QSMZ具有较强的抑制水化能力,并能显著增加岩样单向抗压强度,对煤岩体岩心湿测渗透率的损害均低于30%,干测渗透率恢复值达到95%以上,可作为沁水盆地煤层气井的钻井液和储层钻开液。      

泥页岩吸水扩散系数测量新方法

介绍了一种模拟井下温压条件下泥页岩吸水扩散系数测量的新方法及共实验装置和实验数据回归处理技术.利用该装置对泥页岩的扩散系数值进行了测定,并据此对泥浆滤液在泥页岩井壁中的渗透运移规律进行了数值计算.使用结果表明,该种测量方法新颖科学、数据可靠,且大大的简化了实验过程,缩短了实验时间,所得结果更符合现场实际,具有较大的实用价值.     

大压差泥页岩长裸眼斜井段安全钻井技术

为了实现东濮凹陷深层断块低渗油气资源的低成本开发,采用水平井开发和简化井身结构成为必然的选择。但是作为开发中后期的老油田,地层压力系统紊乱,简化井身结构后,同一裸眼段内高低压共存,易导致滑动钻进压差卡钻和井壁失稳;同时沙一至沙三段泥页岩发育,长裸眼段内井壁坍塌、掉块问题突出。为此,应用横观各向同性模型,考虑水化时间对强度的影响,兼顾井下安全和钻井投资,确定出技术套管的合理下深;优选聚胺抑制剂和梳形聚合物降滤失剂,应用油基钻井液,提高泥页岩地层井壁稳定能力;引入无土相烷基糖苷钻井液,提高润滑性,降低钻进摩阻;应用降压耗钻具组合,解决小井眼清除岩屑问题;设计小弯角螺杆配合欠尺寸稳定器的水平段提速钻具组合,提高机械钻速,降低钻井周期,规避坍塌周期风险,提高复合钻进比例,降低定向滑动压差卡钻风险。7口井的现场应用效果表明,钻井周期缩短了30.95%、卡钻事故降至0次,实现了东濮凹陷大压差泥页岩长裸眼斜井段安全钻井。     

华北北部中元古界洪水庄组页岩地球化学特征： 物源及其风化作用

华北北部洪水庄组黑色页岩是中元古代的富有机质沉积,它可能记录了当时重要的地球化学信息。通过对洪水庄组页岩中的常量和微量元素特征的分析,研究了洪水庄组的物源及其风化作用。高Th/Sc、Al2O3/TiO2、La/Sc、La/Cr、La/Co、Th/Cr和Th/Co值,低Cr/Zr和TiO2/Zr比值,Euan值、Co/Y Ti/Zr关系和La Th Sc组成表明洪水庄组页岩物源主要为上地壳中的长英质花岗闪长岩。洪水庄组页岩的Al、Ca、Na和K组成表明其具有较高的化学蚀变指数（CIA）,同时,元素组成的化学风化作用轨迹反映了洪水庄组页岩受到钾交代作用的影响,可能导致CIA值被低估,其原始CIA值应在90以上。高的原始CIA、化学风化指数（CIW）和斜长石蚀变指数（PIA）表明洪水庄组物源区经历了强烈的化学风化作用。化学风化作用强度以及微量元素组成特征揭示了中元古代洪水庄组沉积时期可能处于温暖潮湿的气候条件,这与中元古代时期大气高CO2浓度以及华北板块古大陆当时位于低纬度地区重建的结果不谋而合。     

Geochemistry of shales from the Upper Miocene Samh Formation,north Marsa Alam,Red Sea,Egypt: implications for source area weathering,provenance, and tectonic setting

The Upper Miocene shales of the Samh Formation, North Marsa Alam along the Egyptian Red Sea coastal plain were analyzed for major and selected trace elements to infer their provenance, weathering intensity, and tectonic setting. The Samh Formation consists of sandstone underlies by shale and marl intercalations. The Samh shales are texturally classified as mudstones. Mineralogically, these shales consist mainly of smectite and kaolinite, associated with non clay minerals (abundant quartz and trace of plagioclase, microcline, and halite). Compared to post-Archaean Australian shales (PAAS), the Samh shales are highly enriched in SiO₂, Al₂O₃, and Fe₂O₃ and depleted in TiO₂, P₂O₅, Na₂O, MgO, and K₂O contents. The K₂O/Al₂O₃ ratio values indicate predominance of clay minerals over K-bearing minerals. Trace elements like zirconium (Zr), Cr, Pb, Sc, Rb, and Cs are positively correlated with Al₂O₃ indicating that these elements are likely fixed in K-feldspars and clays. The Chemical Index of Alteration (CIA), Plagioclase Index of Alteration (PIA), and Chemical Index of Weathering (CIW) values indicate moderate to intense weathering of the source material in a semiarid climate. The geochemistry results suggest that the Samh shales were deposited in a passive margin of a synrift basin and derived from felsic (granitic) source rocks. The inferred tectonic setting for the Upper Miocene Samh shales in Marsa Alam is in agreement with the tectonic evolutionary history of the Eastern Desert of Egypt during the Upper Miocene.     

罗子沟盆地大砬子组油页岩有机地球化学特征及其地质意义

通过对罗子沟盆地大砬子组上段油页岩干酪根镜检、热解、GC 和GC-MS 等分析,并对其有机地球化学多项特征参数进行研究,讨论罗子沟油页岩有机地化特征及其地质意义。根据姥植比及伽马蜡烷、孕甾烷、重排甾烷、重排藿烷等参数特征分析,推测油页岩形成的古湖泊水体性质为淡水--微咸水的还原沉积环境。综合分析显微组分镜检和热解结果及甾烷( C27--C29 ) 分布等参数,认为研究区油页岩有机质主要为混合母源输入。依据热解、Ro、甾烷和C31 升藿烷异构化程度、C29 莫烷/C29 藿烷、 Ts 与Tm 相对含量比值等指标的对比,指出研究区油页岩处于未熟－ 低熟热演化阶段。     

西藏古错-岗巴盆地下白垩统黑色页岩地质特征及其油气资源意义

藏南聂拉木县、岗巴县的古错-岗巴盆地呈东西向展布,位于北喜马拉雅构造分区。早白垩世沉积以碎屑物质为主,其黑色页岩主要集中于下白垩统古错四组、古错五组和东山组。黑色页岩沉积物颗粒微细,以泥质、粘土质组分为主,砂/泥比值低,局部夹有海底扇沉积的细砂岩、粉砂岩等韵律层,富含菱铁矿、钙质结核,少见菊石等生物化石。其沉积环境应为相变缓慢、水体低能且较为特殊（受火山活动影响）的海相还原环境。黑色页岩中的粘土质所反映出的稀土配分模式与玄武岩标准模式极为接近,显示出当时的沉积可能伴随有火山活动及基性物质的介入。综合地质特征显示出本区下白垩统黑色页岩厚度巨大,构造简单,具有较好的成烃条件,虽然有机质成熟度较高,但黑色页岩仍是未来本区油气资源潜力评价中值得重视的积极因素之一。     

Maintaining the stability of deviated and horizontal wells: Effects of mechanical,chemical and thermal phenomena on well designs

Wellbore instability, particularly in shale formations, is regarded as a major challenge in drilling operations. Many factors, such as rock properties, in-situ stresses, chemical interactions between shale and drilling fluids, and thermal effects, should be considered in well trajectory designs and drilling fluid formulations in order to mitigate wellbore instability-related problems. A comprehensive study of wellbore stability in shale formations that takes into account the three-dimensional earth stresses around the wellbore as well as chemical and thermal effects is presented in this work. The effects of borehole configuration (e.g. inclination and azimuth), rock properties (e.g. strength, Young's modulus, membrane efficiency and permeability), temperature and drilling fluid properties (e.g. mud density and chemical concentrations) on wellbore stability in shale formations have been investigated. Results from this study indicate that for low-permeability shales, chemical interactions between the shale and water-based fluids play an important role. Not only is the activity of the water important but the diffusion of ions is also a significant factor for saline fluids. The cooling of drilling fluids is found to be beneficial in preventing compressive failure. However, decreasing the mud temperature can be detrimental since it reduces the fracturing pressure of the formation, which can result in lost-circulation problems. The magnitude of thermal effects depends on shale properties, earth stresses and wellbore orientation and deviation. Conditions are identified when chemical and thermal effects play a significant role in determining the mud-weight window when designing drilling programmes for horizontal and deviated wells. The results presented in this paper will help in reducing the risks associated with wellbore instability and thereby lowering the overall non-productive times and drilling costs.     

宁镇地区下志留统高家边组富有机质页岩孔隙结构

通过氩离子抛光-场发射扫描电镜、小角X射线散射及低温氮气吸附实验,对宁镇地区下志留统仑山5井等高家边组底部富有机质泥页岩孔隙结构进行分析,为下扬子区下志留统富有机质泥页岩的储层评价提供依据。研究表明:高家边组富有机质泥页岩含有大量的纳米级孔隙,包括有机质孔、矿物粒间孔、矿物粒内孔、微裂缝等,孔径分布复杂;优势孔径分布为介孔段,孔隙直径主要为2~50 nm。影响孔径分布的主要因素是矿物组成,脆性矿物和黏土矿物对微孔和介孔都有一定的影响,而有机质含量对泥页岩总体孔隙特征的影响并不明显。     

A Fully Coupled Chemo-Poroelastic Analysis of Pore Pressure and Stress Distribution around a Wellbore in Water Active Rocks

Water active rocks consist of minerals that hold water in their crystalline structure and in pore spaces. Free water from drilling fluid can be attracted by the formation depending on the potential differences between pore space and drilling fluid. The fluid movement into the formation or out of the formation can lead to a change in effective stress, thus causing wellbore failures. In all previous studies it is found that the solute transport from or to the formation is primarily controlled by diffusion process and the effect of advection on solute transfer is negligible for a range of very low permeable shale formations (>10⁻⁵ mD). In this study a range of permeable shale formations (10⁻⁵ to 10⁻³ mD) commonly encountered in drilling oil and gas wells are considered to investigate the solute transfer between drilling fluid and formation due to advection. For this purpose a finite element model of fully coupled chemo-hydro-mechanical processes was developed. Results of this study revealed that the solute transfer between the drilling fluid and the shale formation is controlled primarily by permeability of the shale formations. For the range of shale formations studied here, there exists a threshold permeability below which the solute transfer is dominated by diffusion process and above which by fluid in motion (fluid flow). Results from the numerical experiments have shown that when the permeability of shales is greater than this threshold permeability, the chemical potential gradient between the pore fluid and drilling fluid reaches equilibrium faster than that when the permeability of shales is below this threshold value. Also it has been found that when advection is taken into account, effective radial and tangential stresses decrease around the wellbore, particularly near the wellbore wall where the solute concentration has reached near equilibrium.     

Analysis of Pore Pressure and Stress Distribution around a Wellbore Drilled in Chemically Active Elastoplastic Formations

Drilling in low-permeable reactive shale formations with water-based drilling mud presents significant challenges, particularly in high-pressure and high-temperature environments. In previous studies, several models were proposed to describe the thermodynamic behaviour of shale. Most shale formations under high pressure are expected to undergo plastic deformation. An innovative algorithm including work hardening is proposed in the framework of thermo-chemo-poroelasticity to investigate the effect of plasticity on stresses around the wellbore. For this purpose a finite-element model of coupled thermo-chemo-poro-elastoplasticity is developed. The governing equations are based on the concept of thermodynamics of irreversible processes in discontinuous systems. In order to solve the plastic problem, a single-step backward Euler algorithm containing a yield surface-correction scheme is used to integrate the plastic stress–strain relation. An initial stress method is employed to solve the non-linearity of the plastic equation. In addition, super convergent patch recovery is used to accurately evaluate the time-dependent stress tensor from nodal displacement. The results of this study reveal that thermal and chemical osmosis can significantly affect the fluid flow in low-permeable shale formations. When the salinity of drilling mud is higher than that of pore fluid, fluid is pulled out of the formation by chemical osmotic back flow. Similar results are observed when the temperature of drilling mud is lower than that of the formation fluid. It is found that linear elastic approaches to wellbore stability analysis appear to overestimate the tangential stress around the wellbore and produce more conservative stresses compared to the results of field observation. Therefore, the drilling mud properties obtained from the elastoplastic wellbore stability in shales provide a safer mud weight window and reduce drilling cost.     

陕南川北志留系兰多维列统特列奇阶宁强组的生物礁

志留纪兰多维列世（Llandovery）扬子地台持续上升。特列奇期（Telychian）griestoniensis笔石带上部至spiralis-grandis带代表的时限内,地处扬子地台西北缘的宁强湾,在温暖浅海的环境中沉积了宁强组巨厚的泥页岩,其中夹含8套碳酸盐岩。在与之对应的8期小型局限碳酸盐岩台地的不同部位建造了生物礁和生物滩。生物礁的类型包括骨架礁、生物层和灰泥丘。生物礁群落由底栖固着的造礁珊瑚、苔藓虫、海百合、藻类、层孔虫,以及非固着的附礁生物腕足类、鹦鹉螺、三叶虫等组成。通过宁强广元地区不同地点和层位的生物礁组合分析,论述它们在生态组合、生长形状和发育过程中的多样性。