渤海海域的上第三系油气研究

综述了渤海湾盆地沉积与构造活动在时间与空间上的迁移与演化、烃源岩与储盖层的空间分布规律，结合盆地内的勘探现状分析了渤海湾海域上第三系的油气远景。认为盆地内凸起、低凸起以上第三系为主体，伴有东营组和前第三系油气藏的复式油气聚集带是目前渤海油气勘探最现实的有利目标。     

陡坡带油气藏构造特征与油气聚集规律——以渤海油田旅大6构造为例

旅大6构造是渤海海域新近发现的一个中型油田.该构造位于辽东低凸起中南段陡坡带,为层状构造油气藏,垂向上多层系含油,形成典型的“阶梯式”陡坡带复式油气藏.走滑作用对构造形成、储层发育、断层封堵、油气运移都有重要的作用.构造转折端对沉积卸载形成优质储层具有重要作用,奠定了旅大6构造是辽东低凸起中南段有利成藏区的物质基础;辽中一号断层与区域走滑断层同向,具有走滑压扭性质是控圈断层侧封的关键.南北区块以及东二下段、东三段油气丰度迥异,伸展断层的运移能力和控圈断层的封堵能力共同决定了旅大6构造南区东二下段油气的差异富集成藏.     

南海北部珠江口盆地西区文昌B凹陷油气运聚成藏模式

以南海北部珠江口盆地西部文昌B凹陷构造沉积演化分析为基础,以不同构造带和含油气层系油气成藏特征为依据,将文昌B凹陷及周缘油气运聚成藏模式划分为南部陡坡带扇三角洲骨架砂岩近源垂向运移的古近系断层圈闭聚集成藏模式、南部陡坡带断裂+砂岩垂向运移的新近系背斜圈闭聚集成藏模式、北部缓坡带骨架砂岩近源侧向运移的古近系地层超覆圈闭聚集成藏模式及北部凸起区骨架砂岩+断裂长距离侧向运移的新近系背斜圈闭聚集成藏模式4种类型。在此基础上进一步分析了不同类型油气成藏模式的"源-汇-聚"等油气运聚成藏特征,指出了不同类型油气藏形成与分布的主控因素。同时,根据不同类型油气藏分布富集规律,对文昌B凹陷及周缘有利勘探目标进行了评价预测并经钻探获得了证实,取得了较好勘探成效。     

克百地区二叠系油气分布特征及控制因素

通过对克百地区测井、试油资料的分析,总结了二叠系油气的分布特征,结合构造、沉积发育特征,分析了二叠系油气分布的控制因素。二叠系油气主要分布在佳木河组和上乌尔禾组,平面上油气主要沿地层尖灭线和断层分布,往凹陷中心,油气分布减少。油气藏类型丰富,主要有地层油气藏、断层油气藏、岩性油气藏以及复合油气藏。二叠系油气的分布主要受不整合、断层及岩相展布的控制,由于各控制因素在各层位油气分布中所发挥的作用不同,各层位油气分布也各具特点。     

波斯湾海域古生界胡夫组沉积特征与成藏规律

波斯湾海域古生界蕴藏着巨大的天然气资源。从区域构造演化出发,对该区古生界胡夫组的沉积特征进行分析,建立了"大型缓斜坡碳酸盐岩台地"沉积模式,提出了该区古生界"源-相-势"复合控藏的成藏规律,并指明了下一步勘探方向。研究表明,波斯湾海域胡夫组主要发育台地与台地边缘相区,从波斯湾西北部向东南部依次发育局限—蒸发碳酸盐岩台地、开阔碳酸盐岩台地、台地边缘浅滩—生物礁,纵向上主要为灰岩、白云岩和膏盐的互层沉积。开阔碳酸盐岩台地、台地边缘浅滩—生物礁为有利储层发育相带。波斯湾海域志留系古赛巴段热页岩烃源灶分布及规模控制着胡夫组油气分布与资源规模。胡夫组沉积相带控制油气平面富集区,膏盐盖层控制油气藏纵向与平面分布。热页岩生烃灶周围的低势能古基底高与盐拱构造是古生界主要的油气聚集带,同时,储层物性、油气运移与保存条件是古生界油气成藏的关键。根据资料分析,波斯湾海域南海湾盐次盆胡夫组发育大量盐拱背斜圈闭,且志留系古赛巴段烃源岩与胡夫组圈闭叠合性好,成藏条件优越。该盐拱构造带预测资源量巨大,为波斯湾海域古生界有利勘探方向。     

石臼坨凸起东部斜坡带新近系录井综合解释

石臼坨凸起为渤海海域典型的复式油气聚集区,复杂的油气成藏导致录井资料在全井对比上差异性非常大。随着勘探的深入,在石臼坨凸起东部斜坡带解释符合率较低。对石臼坨凸起东部斜坡带的19口井534层储层进行了综合分析,分析资料包括气测、地化、电测、试油等数据。通过对比分析发现,错误主要集中在新近系的明下段和馆陶组储层,生物降解、荧光、气体组分在认识上存在一些偏差。将生物降解分类,优选参数,建立适应本地区的解释图板和阈值,符合率达到87.7%,效果非常好。东部斜坡带所建立的解释方法对整个石臼坨凸起以后的录井综合解释具有非常大的指导作用。     

基于多尺度资料的体系域划分及其意义——以渤海海域沙垒田凸起东南部东二段为例

不同体系域砂体分布和成藏特征存在明显的差别,正确划分体系域对于油气勘探,特别是隐蔽油气藏勘探具有重要意义。相对于海相地层,由于陆相层序本身的复杂性,并不发育明显的坡折带,在进行体系域划分时,不同学者有不同的划分方案,无论在井上还是地震上很难把握各体系域界面的位置。针对这个问题,结合渤海海域沙垒田凸起东南部东二段体系域划分,提出利用多种不同尺度资料层层控制来划分低位域、湖泛域和高位域的思路方法。这种从尺度较大资料到较小尺度资料层层控制来划分体系域的思路方法,可以避免直接从井上来进行划分导致的错误结论,同时相对湖平面变化曲线法的引用,向建立渤海东营组层序划分的标准迈向了坚实一步。     

南海海域大油气田与中国东南海区油气地质分析

本文以中国南海海域崖１３－１、流花１１－１和大熊油田等三大油气田的地质特征和油气模式为参照，分析了中国东南海域台西南盆地，台湾海峡盆地及毗邻地区的油气地质条件，指出与基底隆起有关的背斜构造、基底风化壳型油气藏、裂隙型油气藏和与裂谷地堑－半地堑构造有关的近源三角洲、缓翼斜坡带等是进一步开展油气勘查的目标和重点。     

渤海湾含油气盆地的地质构造特征与油气田分布规律

渤海湾含油气盆地是继大庆油田发现之后,在我国东部地区所发现的另一个重要的含油气盆地。面积约20万平方公里,包括河北省、山东省北部和西部、辽宁省南部、河南省北部、北京市、天津市和渤海海域。 一、沉积史 渤海湾盆地是一个复式叠加型沉积盆地。新生界、中生界、古生界和震旦亚界地层内广泛分布有多套生储盖组合。具有多旋回、多层系和多油气藏类型的含油气盆地的特色。 晚元古代(震旦亚代)准地槽沉积发展时期: 吕梁运动后,沿着内蒙古陆南缘,张家口——北票深断裂南侧形成一个北东东方向的沉降带,称为燕山准地槽。沉积了晚元古代震旦亚界最厚9400米以碳酸盐岩为主的巨厚沉积(图1)。     

人工神经网络在闵北断块低阻油层识别上的应用

随着油气勘探程度的不断深化,非常规油气藏在油气勘探中不断被发现,在实际的勘探过程中低阻油层的储量和产量都在不断增加。低阻油层作为一种非常规储层,其含油性受多个因素影响。常规测井解释方法评价低阻油层有很大的困难。针对闵桥油田断裂构造错综复杂、油层低阻特征典型、测井解释难度大等特点,利用BP人工神经网络算法,对已知样本进行学习获得识别模式,并使用自编软件,成功识别了闵北断块阜宁组三段低阻油层。识别结果显示,该层新增油井8口,含油面积增加0.53km2,新增石油地质储量23.62万t,经济效益显著;同时深化了对该断块油气分布规律与油藏类型的认识,理论意义重要。     

Structural features and hydrocarbon-bearing potential of gulf of Mexico continental slopes adjacent to the United States

With respect of its structure, the Gulf of Mexico basin is heterogeneous. The following individual basins and subbasins can be distinguished; (1) Mississippi-Louisiana; (2) Gulf Coast within the boundaries of Texas and New Mexico; (3) Mexican Gulf Coast and adjacent system of foredeeps; (4) Yucatan subbasin; (5) Cuba-Bahamas system of foredeeps. Regional seismic studies reveal a close relationship between salt movements and sedimentation. Salt bodies represent excellent cap rocks for hydrocarbon fluids. Anticline folds termed “turtle” structures forming a system of belts appear in the deep parts of the gulf. These structures host large reserves of hydrocarbons, which are concentrated in the Paleogene-Miocene turbidite reservoirs with a porosity approximately 30% overlain by excellent cap rocks (salt, clay) with permeability exceeding 3 darcy. Three productive zones are defined: (1) the folds of the Mississippi River fan; (2) the Perdido belt of anticline folds; (3) Florida. The Paleogene and Miocene-Pliocene-Pleistocene sediments developed on the continental slopes of the Gulf of Mexico basin are the areas most promising with respect to hydrocarbon deposits. On January 1, 2006, the offshore oil production was 53 million tons and the gas production 40 billion cubic meters. Total prospective oil and gas reserves are estimated to be 5.5 billion tons and 4.7 trillion cubic meters, of which over 50% of oil and 1/3 of gas are expected to be discovered on the continental slope.     

世界海相碳酸盐岩油气勘探开发现状与展望

当前国际能源供需矛盾突出,能源安全日益成为各国关注的焦点,碳酸盐勘探开发聚焦了世界的目光。主要大国出于经济和政治利益的考虑,加大对碳酸盐油气勘探开发的投入。世界碳酸盐岩油气探明可采总量为1 434.5×10^8t油当量,其中探明可采石油750.1×10^8t油当量,探明可采天然气684.4×10^8t油当量。世界碳酸盐岩油气田313个,其中油田208个,气田105个。中国碳酸盐岩探明石油15.2×10^8t油当量,探明率为6.5%,探明天然气1.36×10^8m^3,探明率为28.65%。碳酸盐岩油气勘探方法有地质法、地球物理法、地球化学勘探法、钻井法。开发成熟技术有多分支井技术、定向射孔技术、压裂酸化技术等。通过对世界碳酸盐岩资源勘探开发现状研究,实现碳酸盐岩资源优化利用,改善勘探开发效果,必将为全球碳酸盐岩资源的高水平、高效益勘探开发和可持续发展提供理论及实践依据。     

山东胜利油田海洋石油勘探开发现状及前景分析

胜利油田海上勘探区 ,位于渤海湾南部的极浅海海域 ,其范围为 :西起四女寺河口 ,经套儿河口、老黄河口、新黄河口、小青河口 ,东到潍河口 ,海岸长 4 1 4km,胜利矿产登记线内面积 4 870 km2 ,水深一般 0～ 5m,最深 1 8m。截止 2 0 0 0年年底 ,已完成二维地震 71 3 6.1 km,三维地震 1 588.58km2 ,完钻探井 1 0 2口 ,测井解释油气层井 87口 ,试油 85口 ,其中 74口获工业油流 ,6口获低产油流。发现了埕岛、埕北 3 0、新滩 3个油田 ,在明化镇组、馆陶组、东营组、沙河街组、中生界、上古生界、下古生界、太古界中发现了 8套含油层系 ,6种类型的油气藏 ,已探明含油面积 1 45.8km2 ,石油地质储量 3 860 9万 t;控制含油面积57.5km2 ,石油地质储量 894 8万 t,其中埕岛油田是渤海域发现最早的亿吨级油田 ,目前已建成 2 1 6万 t年生产能力 ,累积产油 1 0 57万 t。根据两轮资源评价及勘探实践的认识 ,与本区有关的 8个生油凹陷 (岐口、沙南、渤中、埕北、桩东、青东、莱州湾、潍北 )总资源量约 1 2 .0亿 t,目前已找到探明加控制石油地质储量为 4 .75亿 t,仍有较大的勘探开发潜力。今后将对 8个构造带 (埕子口、埕岛、埕北 3 0、长堤、垦东、青东、青坨子、潍北 )进行勘探 ,落实探明储量 ,进一步投入开发 ,为胜利油田     

Offshore Atlas Project: Methodology and Results

The Offshore Atlas Project (OAP) grouped 4,325 Miocene and older and 5,622 Pliocene and Pleistocene productive sands in the Gulf of Mexico into 91 chronostratigraphic hydrocarbon plays to aid the oil and gas industry with regional hydrocarbon exploration and field development. OAP has produced a two-volume atlas series entitled Atlas of Northern Gulf of Mexico Gas and Oil Reservoirs. Volume 1 comprises Miocene and older reservoirs, while volume 2 comprises Pliocene and Pleistocene reservoirs. Chronozones (Reed et al., 1987) were used to define geologic ages in the Gulf of Mexico. A chronozone is a time-stratigraphic unit defined by a particular benthic foraminifera biostratigraphic zone. The 26 chronozones identified by Reed et al. (1987) were further grouped into 14 Cenozoic and 2 Mesozoic chronozones for OAP. A composite type log (CTL), which shows the chronostratigraphic relationship of all productive sands in a field, was constructed for each of the 876 proved federal fields in the Gulf of Mexico. Depositional facies (retrogradational, aggradational, progradational, and submarine fan)were next identified on each CTL. The four facies were identified primarily according to characteristic SP-curve shapes, paleoecozones, and sand content. The chronozones and depositional facies identified on each CTL were then correlated among fields across the Gulf of Mexico. All productive sands correlated to the same chronozone and depositional facies were then identified as a unique play. Both federal and state fields in the Gulf of Mexico contain original proved reserves (sum of cumulative production and remaining proved reserves) estimated at 12.481 Bbbl of oil and condensate and 156.466 Tcf of gas (40.322 Bboe [sum of liquids and energy equivalent gas]). Of this, 9.943 Bbbl of oil and condensate and 122.263 Tcf of gas (31.698 Bboe) have been produced. Miocene plays contain the most total original proved reserves with 41.9 %, followed by Pleistocene plays (36.2 %), Pliocene plays (18.6 %), Mesozoic plays (2.9 %), and Oligocene plays (0.4 %). Miocene plays have produced the largest amount of total hydrocarbons, as well, at 43.5 % followed by Pleistocene plays (36.5 %), Pliocene plays (19.1 %), Oligocene plays (0.5 %), and Mesozoic plays (0.4 %). Just over two-thirds of the Gulf of Mexico's total original proved reserves are contained in progradational facies (67.4 %),with the remainder comprising submarine-fan facies (18.5 %), aggradational facies (9.9 %), retrogradationalfacies (2.4 %), combination facies (1.7 %), and caprock and reef reservoirs (0.1 %). Total cumulative production from the different facies closely mimics the distribution of original proved reserves. Of the 91 plays, the lower Pleistocene progradational play (LPL P.1) contains the most original proved gas reserves (10.5 %) and has produced the most gas (11.4 %). However, the upper upper Miocene eastern progradational play (UM3 P.1B) contains the most original proved oil and condensate reserves (18.9 %) and has produced the most oil and condensate (21.4%). Several technical studies resulting from OAP have been published. Hunt and Burgess (1995) described the distribution of OAP plays deposited by the ancestral Mississippi River delta system in the north-central Gulf of Mexico over the past 24 million years. The lower Miocene plays are restricted to the westernmost portion of the Louisiana shelf. In the late middle Miocene, the depocenter migrated east of the present-day Mississippi River delta. During the late upper Miocene, the depocenter began migrating back to the west and prograded basinward, and it continued to do so throughout the Pliocene and Pleistocene. Lore and Batchelder (1995) discussed how OAP plays can be used to find exploration targets and assess undiscovered resources. As an exploration tool, OAP play maps can be used to identify conceptual submarine-fan plays downdip of established shallow water producing facies, and to identify wells where a known producing facies or chronozone has not yet been reached. As an assessment tool, the extensive data sets associated with each OAP play can be used to infer statistically the size of undiscovered resources in a play to determine if exploration in that play is economically justifiable. Lore et al. (1995) estimated the amount of undiscovered conventionally recoverable resources in the Gulf of Mexico, basing their assessment on previous work performed for OAP. Mean level estimates show that, by far, submarine-fan plays have the greatest potential for additional oil and gas in the Gulf of Mexico, with 75.1 % and 70.4 % of the total oil and gas resources, respectively. Mean level estimates for the 13 OAP Miocene, Pliocene, and Pleistocene chronozones show that upper Pleistocene plays have the most oil resource potential (24.3 %), while lower Pleistocene plays have the most gas resource potential (20.6 %).     

海上“薄散弱”油藏有效开发实践

“薄散弱”油藏由于其油层薄、砂体小、分布零散、天然能量弱,采用定向井难以经济有效开发;采用水平井开发虽可提高单井初期产量,但由于地层能量不足,产量递减快,无法从根本上解决采收率低的问题;注水开发虽能解决地层能量不足问题,但海上注水要增加设备、平台空间及平台重量,相应地增加开发成本,加上其储量规模小,经济效益难以保证.以X油田H4油藏为例,在储层精细描述的基础上,提出并实践了多底多分支水平井技术与地层自流注水技术,实现了“薄散弱”油藏的经济有效开发,并取得了较好的开发效果.其实践成果对类似难动用储量的经济有效开发具有借鉴和参考意义.     

Geochemical characteristics and isotopic reversal of natural gases in eastern Kopeh-Dagh,NE Iran

Natural gas samples from two gas fields located in Eastern Kopeh-Dagh area were analyzed for molecular and stable isotope compositions. The gaseous hydrocarbons in both Lower Cretaceous clastic reservoir and Upper Jurassic carbonate reservoir are coal-type gases mainly derived from type III kerogen, however enriched δD values of methane implies presence of type II kerogen related material in the source rock. In comparison Upper Jurassic carbonate reservoir gases show higher dryness coefficient resulted through TSR, while presence of C₁C₅ gases in Lower Cretaceous clastic reservoir exhibit no TSR phenomenon. Carbon isotopic values indicate gas to gas cracking and TSR occurrence in the Upper Jurassic carbonate reservoir, as the result of elevated temperature experienced, prior to the following uplifts in last 33–37 million years. The δ¹³C of carbon dioxide and δ³⁴S of hydrogen sulfide in Upper Jurassic carbonate reservoir do not primarily reflect TSR, as uplift related carbonate rock dissolution by acidic gases and reaction/precipitation of light H₂S have changed these values severely. Gaseous hydrocarbons in both reservoirs exhibit enrichment in C₂ gas member, with the carbonate reservoir having higher values resulted through mixing with highly-mature-completely-reversed shale gases. It is likely that the uplifts have lifted off the pressure on shale gases, therefore facilitated the migration of the gases into overlying horizons. However it appears that the released gases during the first major uplift (33–37 million years ago) have migrated to both reservoirs, while the second migrated gases have only mixed with Upper Jurassic carbonate reservoir gases. The studied data suggesting that economic accumulations of natural gas/shale gases deeper than Upper Jurassic carbonate reservoir would be unlikely.     

Northstar-Geology,Exploration History,and Development Status,Beaufort Sea,Alaska

Exploration for oil at Northstar has been long and costly. Northstar leases were first acquired in 1979 at a joint state and federal sale by Shell Oil, Amerada Hess, and Texas Eastern. The Northstar Unit is 6 mi offshore and about 4 mi northeast of the Point McIntyre Field. Oil was first discovered in Shell's Seal Island 1 in 1983. Five additional appraisal wells were drilled (1983-1986) from two man-made gravel islands in 40 ft of water. Early engineering estimates put the cost of development at $ 1.6 billion. In February 1995, BP Exploration (Alaska) acquired a 98 % interest in the Northstar Unit from Amerada Hess and Shell Oil. When developed by BP, Northstar will be the first oil produced from federal leases in Alaska. To date, the oil industry has invested in excess of $ 140 million in exploration and appraisal operations. An additional $ 90 million was spent on lease bonus bids. The giant Prudhoe Bay and Kuparuk Fields lie along the Barrow Arch. This arch is bounded to the north by a rift margin that deepens into the present-day offshore region. Northstar is located among a series of down-stepping faults off this northern rift margin of the Prudhoe Kuparuk high. The structure is a gently south-dipping northwest-trending faulted anticline. The crest of the structure is located near 10,850 ft subsea. The primary reservoir is the Ivishak Formation (325 ft thick) of the Sadlerochit Group. This is the same primary reservoir at Prudhoe Bay, approximately 12 mi to the south. At Northstar the Ivishak is a high-energy, coarse-grained conglomeratic facies of the Ivishak Formation. The primary lithology is a pebbly chert to quartz conglomerate with occasional sandstone. This very high net to gross reservoir appears to contain no regionally continuous permeability barriers. Cementation has reduced primary porosity to less than 15 %. Accurate porosity estimates are difficult to make due to the coarse-grained nature of the lithology and the presence of kaolinite and microporous chert. Permeability is highly variable, but averages 10 to 100 mDarcies. Oil is a very light and volatile 42 API crude with approximately 2,100 ft3 of gas per stock tank barrel of oil. This oil is very different from the heavier oils (26) found to the south in Prudhoe Bay. Estimated recoverable oil reserves range from 100 to 160 million barrels. A free-standing drilling rig is required at Northstar because the reserves are beyond extended-reach drilling techniques from shore-based facilities. The current development plan is to expand the existing Seal Island to about 5 acres. This is significantly less than Endicott's 40-acre island. The proposed drilling and produc tion island will be accessed by summer barges and winter ice roads. Oil, gas, and water will be processed at a stand-alone facility and then sent to shore via a subsurface pipeline. Northstar will have the first Arctic subsea pipeline in Alaska to transport oil to shore facilities (TAPS). Preliminary tests in Spring 1996 were very successful in demonstrating the technology to successfully bury a subsea pipeline safely in the Arctic.     

澳大利亚奥特韦盆地油气地质特征与资源潜力

从区域构造背景和地层沉积特征描述了澳大利亚奥特韦盆地的基础地质特征;从烃源岩、储集层和圈闭三个方面论述了盆地的油气成藏条件;从平面和层系上总结了盆地的油气分布特征。截止到2008年底,该盆地累计生产天然气124.5×10^8m^3,经济和次经济意义的证实储量为石油2×10^6t,天然气350×10^8m^3。对盆地的资源潜力进行评价,并对有利的远景区进行预测。     

Reservoir quality along a homoclinal carbonate ramp deposit: The Permian Upper Dalan Formation,South Pars Field,Persian Gulf Basin

Permo-Triassic carbonate successions host some of the largest oil and gas reserves in the Arabian Plate, including the world's largest gas reservoirs of the Upper Dalan and the Kangan formations in the South Pars Gas Field, Persian Gulf Basin. Both formations are stratigraphically equivalent to the Upper Khuff Formation which has been long recognized as a major oil and gas reservoir in the Arabian Peninsula. The Permian Upper Dalan Formation is composed mainly of mixed carbonate-evaporite sequences that formed on a laterally continuous homoclinal carbonate ramp with significant variations in reservoir heterogeneity and quality. They can be grouped in 18 microfacies. High reservoir qualities are found within high-energy shoal environments with a tendency of the best reservoir quality to occur towards the basin in a mid-ramp setting. In contrast, low-energy tidal flat environments exhibit the poorest reservoir quality. Reservoir quality from lagoonal environments is diverse. Diagenesis has significantly affected reservoir properties by both enhancing and destroying original porosity and permeability. Bivariate plots of porosity and permeability values, combined with thin section petrography indicate that pore-filling “pervasive” and poikilotopic anhydrite cements had the greatest negative impact on the reservoir quality whereas dolomitization and dissolution of grains and cements played the most positive role. Two third-order sequence stratigraphic cycles link lithologies and depositional environments to sea-level fluctuations. HSTs are associated with better reservoir characteristics than TSTs.     

断块油藏储量计算中夹层的识别与剔除

岩性夹层和物性夹层在陆相沉积中非常普遍，通过岩性和物性特征识别取心井夹层，根据不同夹层的测井响应特征识别非取心井的夹层，并按照一定的标准剔除，能更加合理地确定有效厚度，精细表征油藏地质特征，取得客观的储量数据。