Beneficial effects of wettability altering surfactants in oil-wet fractured reservoirs

In fractured reservoirs, an effective matrix-fracture mass transfer is required for oil recovery. Surfactants have long been considered for oil recovery enhancement, mainly in terms of their ability to reduce oil–water interfacial tension. These surfactants are effective when the fractured formations are water-wet, where capillary imbibition of surfactants from the fracture into the matrix contributes to oil recovery. However, another beneficial aspect of surfactants, namely their ability to alter wettability, remains to be explored and exploited. Surfactants capable of altering wettability can be especially beneficial in oil-wet fractured formations, where the surfactant in the fracture diffuses into the matrix and alters the wettability, enabling imbibition of even more surfactant into the matrix. This sequential process of initial diffusion followed by imbibition continues well into the matrix yielding significant enhancements in oil recovery.In order to test this hypothesis of sequential diffusion–imbibition phenomenon, Dual-Drop Dual-Crystal (DDDC) contact angle experiments have been conducted using fractured Yates dolomite reservoir fluids, two types of surfactants (nonionic and anionic) and dolomite rock substrates. A new experimental procedure was developed in which crude oil equilibrated with reservoir brine has been exposed to surfactant to simulate the matrix-fracture interactions in fractured reservoirs. This procedure enables the measurements of dynamic contact angles and oil–water interfacial tensions, in addition to providing the visual observations of the dynamic behavior of crude oil trapped in the rock matrix as it encounters the diffusing surfactant from the fractures. Both the measurements and visual observations indicate wettability alterations of the matrix surface from oil-wet to less oil-wet or intermediate wet by the surfactants. Thus this study is of practical importance to oil-wet fractured formations where surfactant-induced wettability alterations can result in significant oil recovery enhancements. In addition, this study has also identified the need to include contact angle term in the dimensionless Bond number formulations for better quantitative interpretation of rock–fluids interactions.     

稠油微生物开采技术现状及进展

综述了用微生物方法开采稠油的技术现状与进展，论题如下。①概述。②基本方法：异源微生物采油，包括微生物吞吐和微生物驱；本源微生物采油压大港孔店油田的实例。③主要机理，包括产表面活性剂，降解稠油中重质组分及其他。④技术研究，包括机理性、可行性及经济效益研究，列举了国内外6个实例。⑤现场应用，包括国外1个、国内6个实例。⑥该技术的优势及问题。参22。     

MINERALOGICAL, PORE AND PETROPHYSICAL CHARACTERISTICS OF THE DEVONIAN JAUF SANDSTONE RESERVOIR, HAWIYAH FIELD, EASTERN SAUDI ARABIA

Throughout the subsurface of the Arabian Peninsula, the approximately 460ft thick, Devonian Jauf Formation generally consists of well-compacted, low-porosity sandstones and shales, but it also includes friable and highly porous sandstones which form significant gas and condensate reservoir intervals. The mineralogy and pore properties of these reservoir intervals at the Hawiyah field (part of the giant Ghawar structure) were studied by integrating petrographic data with petrophysical measurements of reservoir sandstone samples.
The reservoir sandstones are mainly composed of quartz arenites containing small amounts of altered potassium feldspar grains, authigenic illite and chlorite. Based on the pore types, which reflect the habits of the intergranular clays, three reservoir sandstone types have been defined: Type A, characterized by macroporosity; Type B, with microporosity; and Type C, with combined laminations of Types A and B. The dominance of pore-lining clay (as in Type A) or pore-filling clay (as in Type B) is the principal factor controlling the petrophysical properties of the samples. Types A and C sandstones contain macro pores, but irreducible water saturation is high (25 to 45%) compared to clean samples elsewhere, because of the presence of micropores associated with clay. In Type B sandstones the irreducible water saturation is commonly greater than 40% because all the pores spaces are in the microporosity range. The irreducible water saturation in Type B sandstones increases rapidly as porosity decreases. When porosity is less than 10%, the corresponding permeability is 0.2 mD, but no economic production can be expected because water saturation is as high as 100%. In the producing intervals, authigenic clays result in low electrical resistivity due to high water saturation; however, water-free gas is produced.     

油藏演化的两个极端过程

油气藏形成之后，在地质务件变化不大的情况下，储集层中的油气一般保持相对的稳定。但当地质条件变化较大时，油气藏中则发生明显的蚀变。其中两个极端的演化过程，一是抬升破坏形成生物降解沥青，一是深埋发生原油裂解转化成焦沥青和天然气。生物降解沥青没有一定的形态．在显微镜下呈席状分布，沥青反射率低，抽提物具有明显的生物降解特征。原油裂解形成的焦沥青具有一定的几何形态，沥青反射率很高而无常规抽提物。原油裂解生成的天然气在组分和碳同位素特征上与干酪根裂解生成的天然气有别。图6参15     

三重介质油藏干扰试井压力动态特征

在建立三重介质油藏试井解释模型的基础上，对该类油藏的干扰试井压力动态变化进行了研究；分析了井筒储存、表皮系数、窜流系数以及弹性储容比对观测井井底压力的影响。结果表明，表皮系数对观测井的井底压力没有影响，而井筒储存是否会对观测井井底压力造成影响取决于井筒储存系数的大小以及激动井和观测井之间的距离，窜流系数和弹性储容比对观测井井底压力的影响与单井试井的结果相类似。     

低温低渗透砂岩油藏窜流大孔道深部封堵技术研究

所用堵剂为高强度的淀粉接枝聚丙烯酰胺交联凝胶SAMG-1,由<6%淀粉、4.5%-5.5%丙烯酰胺、0.003%-0.006%交联剂组成,35℃成胶时间受淀粉和交联剂用量控制,为18-20小时以上,成胶前黏度-100 mPa.s。该堵剂具有长期稳定性,在储层岩心中注入深度15 cm的堵剂,在35℃候凝48小时后及老化90天后,封堵强度分别为0.61和0.59 MPa/cm,封堵率分别为98.6%和98.1%。该堵剂优先进入高渗层,注入0.5 PV并成胶后,2组双填砂管组成的模型低、高渗管渗透率保留率分别为68.4%、0.7%和69.4%、0.0%。吉林扶余油田西一区+15-8.2区块有水井6口,油井13口,含水率达91.5%,注入水最快在5天内到达油井。报道了该区块整体深部调剖封堵窜流通道的情况,详细叙述了+15-9.2井施工中通过注入压力和井底回压控制注入流量,使堵剂陆续进入原生和次生孔道的工艺作业,该井设计注入堵剂92 m3。6口水井整体调剖后,油井产液量差别减小,产油量增加,有效期已超过了9个月,共增油843 t,含水平均下降3.87%。图7表1参8。     

大庆长垣外围油田的开发问题

本文在对大庆长垣外围油田的地质情况、油藏类型综合分析评价的基础上,论述了开发这些油田的一系列有关问题。     

岔河集油田开发调整的主要做法与成效

岔河集油田有多个受构造、岩性双重因素控制的中低渗透复杂断块油藏,其主要储集层为河流相沉积。油田20余年的开发历程是典型的滚动勘探开发过程。通过精细科学的地质研究,不断的实践和认识,制定出与其油田地质特点相适应的开发方针,完善了井网部署与加密、产吸剖面调整、油水井配套综合治理等一系列开发对策,并取得了比较好的开发效果。岔河集油田的开发实践对于类似油田开发不乏成功的经验。     

裂缝性油气藏采收率：100个裂缝性油气田实例的经验总结

通过对世界上100个裂缝性油气藏的综合评价，研究储集层及流体本身的性质(包括孔隙度、渗透率、黏度、可动油比例、含水饱和度、润湿性及裂缝分布特征等)和驱动机制及油藏管理战略(优化日产量和采用不同类型的提高采收率技术)对其最终采收率的影响。将裂缝性油气藏分为4类：I类的基质几乎没有孔隙度和渗透率，裂缝是储存空间和流体流动的通道；Ⅱ类的基质有较低的孔隙度和渗透率，基质提供储存空间，裂缝提供流动通道；Ⅲ类(微孔隙)的基质具有高孔隙度和低渗透率，基质提供储存空间，裂缝提供流动通道；Ⅳ类(大孔隙)的基质具有高的孔隙度和渗透率，基质提供储存空间和流动通道，裂缝仅增加渗透率。对26个Ⅱ类油气藏和20个Ⅲ类油气藏的开采历史的研究表明：Ⅱ类油气藏的采收率受水驱强度和最优日产量控制，日产量过高会很容易破坏Ⅱ类油气藏，一些Ⅱ类油气藏如果管理得当，采收率可以很高，不需要二次或三次采油；Ⅲ类油气藏的采收率主要受岩石和流体本身性质的影响，特别是基质渗透率、流体重度、润湿性以及裂缝强度等，不进行二次或三次采油不可能完全开采，往往需要采用一些提高采收率的专门技术。以往将Ⅱ类和Ⅲ类裂缝性油气藏归为一类，认识它们的区别将有助于选择更好的开发策略。     

Practical Equivalent Continuum Model for Simulation of Jointed Rock Mass Using FLAC3D

A simple practical equivalent continuum numerical model for simulating the behavior of jointed rock mass has been extended to three-dimensional using FLAC3D. This model estimates the properties of jointed rock mass from the properties of intact rock and a joint factor (Jf), which is the integration of the properties of joints to take care of the effects of frequency, orientation, and strength of joint. A new FISH function has been written in FLAC3D specifically for modeling jointed rocks using the Duncan and Chang hyperbolic model. This model has been validated first with simple element tests at different confining pressures for different rocks with different joint configurations. Explicit modeling of the joints has also been done in element tests and results obtained compare well with the results of equivalent continuum model and also with experimental results. Further, this has been applied for a case study of a large underground power house cavern in the Himalayas. The analysis has been done under various stages of excavation, assigning a null model available in FLAC3D for simulating the excavation.