安塞油田三叠系延长组长10油层组沉积相研究

Ordos basin is a large-scale craton overlapping basin, which locates in western North China platform and possesses abundant hydrocarbon resources. Ansai area in 2007 to extend the head of Chang10 of Yangchang Formation has made breakthrough progress in the region, long a high of Gao52 was Chang10 industrial oil flow, for oil exploration Ansai Oil Field opened a new chapter. in 2008, high of Gao52, Wang519, Gao34 producing wells area of building and found the existence of Chang10 great potential for the discovery of Chang10 Reservoir, Ansai Oil Field for a new direction, showing a good exploration development prospects.The study of occurrence and distribution features of hydrocarbon should be made by new theories and evolutions of sedimentology, sequence stratigraphy, reservoir sedimentology and petroleum geology form different angles on the base of regional geology background. Ansai Oil Field is in mid Shanbei Slope, which is a considerable producing zone of Ordos basin. Chang10 of Yangchang Formation is an important oil-bearing series, which sedimentary formation was formed in Indosinian orogeny, Late Triassic, sedimentary background is a momentary uplifting in Ordos basin, and exploration and exploitation of hydrocarbon in this area is very important. To further descripte disciplinarian of accumulation hydrocarbon, carefully study on sedimentary facies, reservoir type and disciplinarian of accumulation hydrocarbon of Chang10 of Yangchang Formation in study area is needed. By collecting date of field profile, outcrop, core and many other geological, through sedimentary and oil geological analysis, sedimentary facies types were identified, distributing of sedimentary facies and extension of sand body were analyzed too. Finally, the main controlling factors of hydrocarbon and the favorable areas were found out by deeply studying sedimentary system and disciplinarian of accumulation oil&gas in Chang10 of Yangchang Formation, Late Triassic in Ansai Oil Field. Chang10 of Yangchang Formation is main study formation, which is divided into three members (Chang101, Chang102 and Chang103), Chang101 is subdivided into three (Chang1011, Chang1012and Chang1013) reservoirs. By defining Layered borderline between every member and detailed describing rock and electro characteristic, member zonation become more reasonable and accurate also sedimentary facies and disciplinarian of accumulation oil&gas in study area are confirmed Through researching sedimentary facies, reservoir sand and hydrocarbon migration, accumulation, distribution, hydrocarbon accumulation models of Chang10 of Yangchang Formation in study area is pointed out, which is lithologic hydrocarbon reservoir and tectonic-lithologic hydrocarbon reservoir. Different play is formed by different processes and factors. Through analysis of reservoir property, trap type and accumulation model, several favorable exploration areas can be found out in Chang 10 reservoirs （Chang1011, Chang1012and Chang1013） of the Ansai Oil Field.

塔里木盆地寒武－奥陶系白云岩类型、成因机理及其孔隙性研究

Cambrian-Ordovician dolostones in Tarim Basin are hydrocarbon reservoir rocks of vital importance. Under the guidance of the theories of sedimentology and the sedimentology of carbonate reservoir, based on the first-hand qualitative and quantitative data especially, combined with micro-study, geochemical and reservoir capacity analysis, and precursor research, the origin and reservoir characteristics of the dolostones were discussed. Based on detailed petrographic investigations, four types of dolostone have been recognized, which are, respecitively, mud-silt-sized dolostones, algal laminated dolostones (ALD), prophyritic dolostone, and neomorphic dolostone. Mud-silt-sized dolostones always presents as laminas together with evaporated signatures, its REE patterns and ΣREE are all close to that of the finely crystalline limestone. This kind of dolomite probably experienced relatively low fluid-rock ratio during diagenesis was formed in hypersaline and oxidizing environment and involved fast dolomitization process. It was dolomitized by evaporated seawater in sabkha environment.The main primary fabrics of algal lamination in algal laminated dolomite (ALD) can still be identified and its ΣREE (21.37) is very close to that of algae. This reveals that ALD was dolomitized during early diagenesis and algae possibly played an important role. The ALD was formed under mediation of organic matter and Mg2+ were supplied by magnesium concentrated algal laminites and sea water. Prophyritic dolostones presents mainly as patchy occurrence and yield the lowest δ13C and Z value. Its ΣREE is much less than that of the finely crystalline limestone. These characteristics reveal that the cloudy cores were dolomitized in shallow early diagenetic environments by pore fluids riched in Mg2+. Whereas the clear rims were likely formed in subsequent burial into deeper subsurface environments, and the Mg2+ needed for further dolomitization possibly was supplied by the transformations of clay minerals. Neomorphic dolostones consist of coarse, turbid crystals and exhibits sucrosic and mosaic textures. It has highest Fe2+ contents and average homogeneous temperature (110.2℃). Collectively, these characteristics demonstrate that the neomorphic dolostones was likely formed by recrystallization of pre-existing dolomites during deep burial. The ΣREE of the four types of dolostone distinctly differentiates from each other. However, their REE patterns are all enriched in LREE, depleted in HREE and have Eu negative anomalies. Its ΣREE 13.64 ppm, less than 1/4 of finely crystalline limestone, and ranks the lowest in the 4 types.These characteristics are comparable to those of finely crystalline limestone, and are mainly infuenced by the sea water. These four types of dolostone show similar REE mobility behaviour and no significant fractionation, althouth they have been subjected to evidently different diageneses. Seven main pore types are identified in the dolostones , which are fenestral, moldic, intercrystal, dissolved，breccia, dissolved breccia and stylolite pores. Fenestral pores are primary and the others are secondary. The dissolved pores and intercrystal pores are the most important reservoir spaces and followed by breccias and dissolved breccia pores, and the moldic and fenestral pores are less important. Stylolites can enhance permeability of reservoir rocks in one hand, for the other hand, the capacity of reservoir and permeability are enhanced and then better reservoir rocks can be formed when they are combined with patchy dolostones. The relationship between porosity and the type of dolostones is that the dissolved neomorphic dolostones have the highest porosity of 3.65%, than followed by dissolved Mud-silt-sized dolostones of 3.35%. The mud-silt-sized dolostones without dissolution have the lowest porosity of 0.90%. Moreover, the porosity of prophyritic dolostones and the neomorphic dolostones without dissolution are lower, respectively 1.675% and 1.41%. Although algal laminated dolostones consist of euhedral crystals and riched in intercrystal pores, its porosity just yields 1.20%. The relationship between permeability and the type of dolostones is that that algal laminated dolostones have the highest permeability of 0.462mD and followed by 0.065mD of prophyritic dolostones. Dissolution have no significant influence on the permeability of neomorphic dolostones and this presented by the permeability of dissolved and non-dissolved are very close, respectively 0.043mD and 0.062mD. No matter dissolved or not, mud-silt-sized dolostones are much less permeable. The permeability of non-dissolved and dissolved are 0.051mD and 0.016mD. Collectively, in the study area, neomorphic dolostones can form high quality reservoir.

济阳-昌潍坳陷火成岩油气藏体系形成机理和分布规律研究

Jiyang & Changwei depressions are two neighboring depressions in Bahai Bay Basin, the famous oil rich basin in East China. The exploration activities in the past 40 years has proved that, within the basins, there exists not only plentiful sandstone hydrocarbon reservoirs (conventional), but also abundant special reservoirs as igneous rock, mudstone and conglomerate ones which have been knowing as the unconventional in the past, and with the prospecting activity is getting more and more detailed, the unconventional reservoirs are also getting more and more important for further resources, among which, the igneous lithological reservoir be of significance as a new research and exploration area. The purpose of this paper is, with the historical researches and data as base, the System Theory, Practice Theory and Modern Comprehensive Petroleum Geology Theory as guide, the theoretical and practice break through as the goal, and the existing problems in the past as the break through direction, to explore and establish a valid reservoir formation and distribution models for igneous strata in the profile of the eastern faulted basins. After investigating the distribution of the igneous rocks and review the history of the igneous rocks reservoirs in basins, the author focused on the following issues and correspondingly the following progresses have been made: 1.Come to a new basin evolution and structure model named "Combined-Basin-bodies Model" for Jiyang even Eastern faulted basins based on the study on the origin and evolution of Jiyang & Changwei basins, depending on this model, every faulted basin in the Bo-hai Bay Basin is consisted of three Basin-Bodies including the Lower (Mesozoic), Middle (Early Tertiary) and the Upper (Late Tertiary) Bodies, each evolved in different geo-stress setting and with different basin trend, shape and igneous-sedimentary buildings system, and from this one to next one, the basin experienced a kind of process named "shape changing" and "Style changing". 2. Supposed a serious of new realizations as follows (1) There were "multi-level magma sources" including Upper mantel and the Lower, Middle and even the Upper Shell magma Chambers in the historical Magma Processes in the basins; (2) There were "multi-magma accessing or pass" from the first level (Mantel faults) to the second, third and fourth levels (that is the different levels of fault in the basin sediment strata) worked in the geo-historical and magma processes; (3) Three tectonic magma cycles and more periods have been recognized those are matched with the "Basin -body-Model" and (4)The geo-historical magma processes were non-homogeneous in time and space scale and so the magma rocks distributed in "zones" or "belts". 3. The study of magma process's effect on basin petroleum conditions have been made and the following new conclusions were reached: (1) the eruptive rocks were tend to be matched with the "caped source rock", and the magma process were favorable to the maturing of the source rocks. (2) The magma process were fruitful to the accumulation of the non-hydrocarbon reservoirs however a over magma process may damage the grade of resource rock; (3) Eruptive activity provided a fruitful environment for the formation of such new reservoir rocks as "co-eruptive turbidity sandstones" and "thermal water carbonate rocks" and the intrusive process can lead to the origin of "metamorphism rock reservoir"; (4) even if the intrusive process may cause the cap rock broken, the late Tertiary intrusive rocks may indeed provide the lateral seal and act as the cap rock locally even regionally. All above progresses are valuable for reconstructing the magma-sedimentary process history and enriching the theory system of modem petroleum geology. 4. A systematic classification system has been provided and the dominating factors for the origin and distribution of igneous rock reservoirs have been worked out based on the systematic case studies, which are as follows: (1) The classification is given based on multi-factors as the origin type, litho-phase, type of reservoir pore, reservoir ability etc., (2) Each type of reservoir was characterized in a detailed way; (3) There are 7 factors dominated the intrusive reservoir's characteristics including depth of intrusion, litho-facies of surrounding rocks, thickness of intrusive rock, intrusive facies, frequency and size of the working faults, shape and tectonic deformation of rock, erosion strength of the rock and the time of the intrusion ect., in the contrast, 4 factors are for eruptive rocks as volcanic facies, frequency and size of the working faults, strength of erosion and the thermal water processing. 5. Several new concept including "reservoir litho-facies", "composite-volcanic facies" and "reservoir system" ect. Were suggested, based on which the following models were established: (1) A seven reservoir belts model for a intrusive unit profile and further more, (2) a three layers cubic model consisted of three layer as "metamorphic roe layer", "marginal layer" and "the core"; (3) A five zones vertical reservoir sequence model consisted of five litho-facies named A, B, C, D and E for a original lava unit and furthermore three models respectively for a erosion, subsidence and faulted lava unit; (4) A composite volcanic face model for a lava cone or a composite cone that is consisted of three facies as "crater and nearby face", "middle slope" and "far slope", among which, the middle slope face is the most potential reservoir area and producible for oil & gas. 6. The concept of "igneous reservoir" was redefined as the igneous, and then a new concept of "igneous reservoir system" was supposed which means the reservoir system consisted of igneous and associated non-igneous reservoirs, with non-hydrocarbon reservoir included. 7. The origin and distribution of igneous reservoir system were probed and generalized for the exploration applications, and origin models of the main reservoir sub-systems have been established including those of igneous, related non-igneous and non-hydrocarbon. For intrusive rocks, two reservoir formation models have been suggested, one is called "Original or Primary Model", and the another one is "Secondary Model"; Similarly, the eruptive rock reservoirs were divided in three types including "Highly Produced", "Moderately Produced" and "Lowly Produced" and accordingly their formation models were given off; the related non-igneous reservoir system was considered combination of eight reservoirs, among which some ones like the Above Anticline Trap are highly produced; Also, the non-hydrocarbon. Trap system including five kinds of traps was discussed. 8. The concept models for four reservoir systems were suggested, which include the intrusive system consisted of 7 kinds of traps, the land eruptive system with 6 traps, the under water eruptive system including 6 kinds of traps and the non-hydrocarbon system combined by 5 kinds of traps. In this part, the techniques for exploration of igneous reservoir system were also generalized and probed, and based on which and the geological progresses of this paper, the potential resources and distributions of every reservoir system was evaluated and about 186 millions of reserves and eight most potential non-hydrocarbon areas were predicted and outlined. The author believe that the igneous reservoir system is a very important exploration area and its study is only in its early stage, the framework of this paper should be filled with more detailed studies, and only along way, the exploration of igneous reservoir system can go into it's really effective stage.

吐哈盆地山前带构造岩相带及油气藏预测研究

This paper based on the example of mountain front tectonic belt of Tuha basin - a typical basin in west China, using geological, logging and seismic data, combining the two methods-comprehensive analysis of geological-geophysical data and numerical simulation together, studies the types of tectonic lithofacies and the mechanism of oil/gas accumulation in mountain front tectonic belt, and predicts favorable exploration areas. The tectonic lithofacies in periphery belt of compressional basin is systematically studied for the first time. The distribution and systematically analyzed with geological, logging and seismic data; the bury history of formations in the mountain front are restored with the back-stripping technique; the tectonic depression history of the mountain front is studied according to Airy Balanced Model; the tectonic evolution history is restored with the balanced section technique; according to the space composition of tectonic units and sedimentary systems of different geological time, the tectonic facies belt of the middle and lower Jurassic in the piedmont is divided into 12 types, and the controls of each type's tectonic lithofacies belt on the conditions of oil/gas generation, reservation and sealing are analyzed in depth. 3D numerical simulation and analysis is applied to the tectonic stress field in the hydrocarbon reservoir-forming-period for the first time. Because of the complex evolution of mountain front of Tuha basin, 3D numerical simulation of tectonic stress field in the hydrocarbon reservoir-forming-period helps to study the magnitude of the maximum principal stress, the minimum principal stress and the shear stress, the range and distribution of the principal stress, and controls of the upwards factors on the oil/gas migration and accumulation. Through the study on the oil-controlling fault's evolution, sealing mechanism and sealing history, the coupling of two effects of the fault-passage and sealing screen for oil/gas migration can be defined. Using the basic principle of petroleum system analysis, the paper systematically studies the hydrocarbon reservoir-forming mechanism and the time-space matching of the factors that affect the formation of reservoir, such as the space matching of active oil/gas matching of the active period of fault, the migration period of oil/gas and the formation period of trap. Through comprehensive analysis, the favorable exploration targets are selected in selected in the mountain front.

东营凹陷辛镇复杂断块油藏形成机制和剩余油分布规律研究

In this paper, the complex faulted-block oil reservoir of Xinzhen area in Dongying depression is systematically studied from basic conditions forming faulted-block oil and gas reservoir integrating geology, seismic, logging and reservoir engineering information and computer; guided by petroleum geology, geomechanics, structural geology and geophysics and other theories. Based on analysis of background condition such as regional strata, structure and petroleum geology, structural research on geometry, kinemaitcs and dynamics, oil-controlling fault research on the seal features, sealing mechanism and sealing pattern, and research on enrichment rules and controlling factors of complex faulted-block oil reservoir are carried out to give out the formation mechanics of oil reservoir of Xinzhen complex faulted-block oil reservoir. As a result, the reservoir formation pattern is established. At the same time, through dissecting the characteristics and hydrocarbon enrichment law of complex faulted-block oil reservoir, and studying its distribution law of remaining oil after entering extra high water-cut period, a set of technologies are formed to predict complex faulted-block oil reservoir and its remaining oil distribution and to enhance oil recovery (EOR). Based on the time relationship between migration of hydrocarbon and trap formation, accumulating period of Xinzhen oil reservoir is determined. The formation of Xinzhen anticlinal trap was prior to the primary migration. This is favorable to formation of Xinzhen anticlinal hydrocarbon reservoir. Meanwhile, because anticline top caving isn't at the sane time as that of moving or faulted-trap forming inner anticline, oil and gas migrated many times and Xinzhen complex faulted-block oil reservoir formed from ES_3~(upper) to EG. Accumulating law and controlling factors of complex faulted-block reservoir are analyzed from many aspects such as regional structure background controlling hydrocarbon accumulating, plastic arch-open structure controlling oil-bearing series and reservoir types, sealing-opening of fault controlling hydrocarbon distribution and structure pattern controlling enriched trap types. Also, we established the structure pattern in Xinzhen a'ea: the arch-open of underlying strata cause expanding fracture. The main block groups developed here are shovel-like normal fault block group in the north area of Xinzhen and its associated graben block group. Block groups dominate the formation and distribution of reservoirs. We studied qualitatively and quantitatively the sealing characteristics, sealing history and sealing mechanism of faults, too. And, the sealing characteristics are evaluated and the distribution pattern of hydrocarbon controlled by faults is researched. Due to movement intensity of big faults, deep falling of downthrown block, high degree of repture and development of fracture, shallow layers close to the downthrown block of secondary faults are unfavorable to hydrocarbon accumulation. This is confirmed by the exploration practice in Xinzhen anticline. In terms of the downthrown blocks of sencondary contemporaneous faults lied in the south and north area of Xinzhen, hydrocarbon is poor close to fracture belt, while it is relatively abundant in tertiary companion faults. Because of long-term movement of faults that control hydrocarbon, fi'om ES3 to EG, six set of oil-bearing series formed. And their opening causes the inhomogeneity in hydrocarbon abundance among each block--in two flanks of anticline reservoirs are abundant while in the axial area, oil and gas are sporadic. There the sealing characteristics control oil-bearing area of oil/gas accumulation and the height of oil reservoir. Longitudinally, oil and gas are enriched in dip-flat areas in mid-plane of faults. It is established that there are four types of accumulating patterns in complex faulted-block oil reservoirs in Xinzhen. The first is accumulating pattern of lithologic oil reservoirs in E~S_3~(mid-lowwer), that is, self-generating-self-reserving-self-covering lithologic trap pattern. The second is drag-anticline accumulating pattern in Xinzhen. The structure traps are drag anticlines formed by the contemporaneous faults of the second basement in the north of Xinzhen, and the multiple source rocks involve Ek_2, Es_4, Es_3 and Es_1 members. The reservoirs are fluvial-delta sandstones of the upper member of Shahejie formation and Guantao formation, covered by regional thick mudstone of the upper member of Guantao formation and MingHuazhen formation. The third is the accumulating pattern of reverse listric fault, the third-degree fault of Xinzhen anticline limb and the reservoirs form reservoir screened by reverse listric faults. The forth is accumulating pattern of crossing faults which form closing or semi-closing faulted-blocks that accumulate hydrocarbon. The technologies of predicting remaining oil in complex faulted-block reservoir during the mid and late development stage is formed. Remaining oil in simple large faulted-blocks enriches in structural high, structural middle, structural low of thick bottom water reservoirs, points near bent edge-fault oftertiary faults and part the fourth ones with big falling displacement, microstructure high place of oil-sandbodies and areas where local well pattern isn't perfect. While that in small complex faulted-blocks enriches near small nose, small high point, angle of small faults, small oil-bearing faulted-blocks without well and areas with non-perfect well pattern. The technologies of enhancing recovery factor in complex faulted-block reservoir during the mid and late development stage is formed as follows: fine reservoir description, drilling adjust wells, designing directional wells, sub-dividing layer series of development, improving flooding pattern, changing water-injection direction and enhancing swept volume, cyclic waterflooding and gas-injection, etc. Here, directional wells include directional deflecting wells, lateral-drilling wells, lateral-drilling horizontal wells and horizontal wells. The results of this paper have been used in exploration and development of Shengli oilfield, and have achieved great social and economic profit, especially in predicting distribution of complex faulted-block reservoir, remaining oil distribution during middle and late stage of development, and in EOR. Applying the achievement of fault-closure research, new hydrocarbon-bearing blocks are discovered in flanks of Dongying central uplift and in complex blocks with proved reserves 15 million tons. With the study of remaining oil distribution law in complex faulted-block reservoirs, recovery factors are increased greatly in Dongxin, Xianhe and Linpan complex faulted-block reservoirs and accumulated oil production increment is 3 million tons.

东营凹陷成藏组合体研究与勘探实践

With the development of petroleum exploration, subtle reservoir has become the main exploration object in Dongying Depression, which requires some new technologies and methods to further reveal the geological characteristics in step with the mature exploration stage. In this paper, on the references to the studies of petroleum system and multiple oil-gas accumulation belt with flexible maneuverability, and the application of systematic theory, the concept of reservoir assemblage is initially defined as "the association of active source rock(s) and hydrocarbon reservoir(s) that are genetically related, with the bridge of pathway system in an oil and gas bearing basin". Compared with the theories of petroleum system and multiple oil-gas accumulation belts, it emphasizes on the processes of petroleum migration and accumulation and the correlation among active source rock, trapped hydrocarbon and migration pathway, and has been confirmed to be more suitably applied to high maturely explored basin. In the first study of this paper, sequence stratigraphy and subtle analytical technology of source rock have been employed to find that two categories of source rock with their characteristic types of organic matter and substantial states occurred in Dongying Depression. The first category, consisting of the oil shales within the third-order sequences of lacustrine expanding system tracts in the upper interval of the fourth Member of Shahejie Formation and both in the middle and lower intervals of the third Member of Shahejie Formation, is featured with the highest abundance of total organic matter (TOC) and the strongest abilities of hydrocarbon generation and expulsion, which is classified into the standard of good hydrocarbon source rock. Exploration assessment confirmed that about 70-80% of hydrocarbon in Dongying Depression came from this set of source rock for which the low sedimentary rate and strong oxygen-free environment would play the key role during its generation. The second category, composed of organic matter of dark mudstone in high stand system tracts in the upper and middle intervals of the third Member of Shahejie Formation, has been characterized by low content of total organic matter which mostly dispersedly distributes, and formed in the pre-delta to delta front environments. In classification, it belongs to the ordinary standard of source rocks. In the second research part, through the studies of high frequency sequence stratigraphy, fault geometry and active history combining with geochemistry of fluid inclusion and nitrogen compound and simulation test of hydrocarbon migration and accumulation, the faults have been thought to be the principal conduits, and the sandy bodies and unconformities might played the complementary pathways for hydrocarbon migration and accumulation in Dongying Depression of the continental faulted basin. Therefore, the fault activities may mainly constrain on the development of hydrocarbon pathways in space and time. Even more, using homogenization temperatures of fluid inclusion in digenetic minerals, three critical moments for hydrocarbon accumulation have been determined as well in Dongying Depression, which happened during the late stage of Dongying Formation (Ed), the early stage of Guantao Formation (Nig) and the early stage of Minghuazhen Formation (Nim), respectively. Comparatively, the last stage is looked as the main forming-reservoir period, which has also been supported by the results of geochemical analysis and simulation experiments of hydrocarbon generation and expulsion. Clearly, the times of hydrocarbon migration and accumulation are consistent with those of the fault activities in Dongying Depression, which indicate that tectonic activities would control the forming-reservoir. A conceptual model of faulting-episodic expulsion coupled with episodic forming-reservoir has then been established in this study. In the third part of this paper, some focusing areas were selected for the fine descriptions of pathway distribution and forming-reservoir, which has given four types of reservoir assemblage in terms of the main pathway and its correlation with the reservoir and trap: (1) mainly consisted of sandy bodies; (2) mainly consisted of faults; (3) mainly consisted of unconformities; and (4) their complex with two or three types of pathways. This classified criteria has also been applied to access the risk of some prospected traps in Dongying Depression. Finally, through the application of reservoir assemblage integrated with pathway distribution to all the prospective targets in Dongying Depression, the new favorably hydrocarbon accumulated belts have been figured out, and more subtle reservoirs have also been found. For examples, during 2000 and 2002, in the mature exploration areas, such as Liangjialou and Shengtuo structural closures etc., newly proved reserves were 2274 * 104t, and forecasted oil reserves 5660-5860xl04t; and in the predicted favorable areas, newly additional controlled oil reserves was 3355xl04t. Besides those, many other favorable exploration areas need to be further appraised.

Velocities of compressional and shear waves in limestones

Carbonate rocks are important hydrocarbon reservoir rocks with complex textures and petrophysical properties (porosity and permeability) mainly resulting from various diagenetic processes (compaction, dissolution, precipitation, cementation, etc.). These complexities make prediction of reservoir characteristics (e.g. porosity and permeability) from their seismic properties very difficult. To explore the relationship between the seismic, petrophysical and geological properties, ultrasonic compressional- and shear-wave velocity measurements were made under a simulated in situ condition of pressure (50 MPa hydrostatic effective pressure) at frequencies of approximately 0.85 MHz and 0.7 MHz, respectively, using a pulse-echo method. The measurements were made both in vacuum-dry and fully saturated conditions in oolitic limestones of the Great Oolite Formation of southern England. Some of the rocks were fully saturated with oil. The acoustic measurements were supplemented by porosity and permeability measurements, petrological and pore geometry studies of resin-impregnated polished thin sections, X-ray diffraction analyses and scanning electron microscope studies to investigate submicroscopic textures and micropores. It is shown that the compressional- and shear-wave velocities (V-p and V-s, respectively) decrease with increasing porosity and that V-p decreases approximately twice as fast as V-s. The systematic differences in pore structures (e.g. the aspect ratio) of the limestones produce large residuals in the velocity versus porosity relationship. It is demonstrated that the velocity versus porosity relationship can be improved by removing the pore-structure-dependent variations from the residuals. The introduction of water into the pore space decreases the shear moduli of the rocks by about 2 GPa, suggesting that there exists a fluid/matrix interaction at grain contacts, which reduces the rigidity. The predicted Biot-Gassmann velocity values are greater than the measured velocity values due to the rock-fluid interaction. This is not accounted for in the Biot-Gassmann velocity models and velocity dispersion due to a local flow mechanism. The velocities predicted by the Raymer and time-average relationships overestimated the measured velocities even more than the Biot model.

Caracterização geométrica de um sistema fluvial, formação Ttaquaquecetuba, Terciário da Bacia de São Paulo

The objective of this study is the geometric characterization of a fluvial system, exemplified by the Itaquaquecetuba Formation. The studied area is a quarry located in Itaquaquecetuba, distant 35 km from the city of São Paulo, which is inserted in the context of São Paulo Basin. Fluvial systems are important hydrocarbon reservoirs, and this study may contribute with an analogue for ancient reservoirs. It was elaborated ten facies logs along a distance of 200 m (log spacing of 20 m), with a vertical column (thickness) of 40 m for each log. Eight facies cycles, and its lateral chrono-correlation allowed to map the potential reservoir and non-reservoir facies within each cycle. Regarding the depositional model for the studied section, it is assumed an alluvial fan system composed of meandering and ribbon-type fluvial channels.

Modelagem numérica de dados MCSEM 3D usando computação paralela

Desenvolvemos a modelagem numérica de dados sintéticos Marine Controlled Source Electromagnetic (MCSEM) usada na exploração de hidrocarbonetos para simples modelos tridimensionais usando computação paralela. Os modelos são constituidos de duas camadas estrati cadas: o mar e o sedimentos encaixantes de um delgado reservatório tridimensional, sobrepostas pelo semi-espaço correspondente ao ar. Neste Trabalho apresentamos uma abordagem tridimensional da técnica dos elementos nitos aplicada ao método MCSEM, usando a formulação da decomposição primária e secundária dos potenciais acoplados magnético e elétrico. Num pós-processamento, os campos eletromagnéticos são calculados a partir dos potenciais espalhados via diferenciação numérica. Exploramos o paralelismo dos dados MCSEM 3D em um levantamento multitransmissor, em que para cada posição do transmissor temos o mesmo processo de cálculos com dados diferentes. Para isso, usamos a biblioteca Message Passing Interface (MPI) e o modelo servidor cliente, onde o processador administrador envia os dados de entradas para os processadores clientes computar a modelagem. Os dados de entrada são formados pelos parâmetros da malha de elementos nitos, dos transmissores e do modelo geoelétrico do reservatório. Esse possui geometria prismática que representa lentes de reservatórios de hidrocarbonetos em águas profundas. Observamos que quando a largura e o comprimento horizontais desses reservatório têm a mesma ordem de grandeza, as resposta in-line são muito semelhantes e conseqüentemente o efeito tridimensional não é detectado. Por sua vez, quando a diferença nos tamanhos da largura e do comprimento do reservatório é signi cativa o efeito 3D é facilmente detectado em medidas in-line na maior dimensão horizontal do reservatório. Para medidas na menor dimensão esse efeito não é detectável, pois, nesse caso o modelo 3D se aproxima de um modelo bidimensional. O paralelismo dos dados é de rápida implementação e processamento. O tempo de execução para a modelagem multitransmissor em ambiente paralelo é equivalente ao tempo de processamento da modelagem para um único transmissor em uma máquina seqüêncial, com o acréscimo do tempo de latência na transmissão de dados entre os nós do cluster, o que justi ca o uso desta metodologia na modelagem e interpretação de dados MCSEM. Devido a reduzida memória (2 Gbytes) em cada processador do cluster do departamento de geofísica da UFPA, apenas modelos muito simples foram executados.

Modelagem do mCSEM no domínio do tempo usando transformada discreta de Fourier

A modelagem do mCSEM é feita normalmente no domínio da frequência, desde sua formulação teórica até a análise dos resultados, devido às simplificações nas equações de Maxwell, possibilitadas quando trabalhamos em um regime de baixa frequência. No entanto, a abordagem através do domínio do tempo pode em princípio fornecer informação equivalente sobre a geofísica da subsuperfície aos dados no domínio da frequência. Neste trabalho, modelamos o mCSEM no domínio da frequência em modelos unidimensionais, e usamos a transformada discreta de Fourier para obter os dados no domínio do tempo. Simulamos ambientes geológicos marinhos com e sem uma camada resistiva, que representa um reservatório de hidrocarbonetos. Verificamos que os dados no domínio do tempo apresentam diferenças quando calculados para os modelos com e sem hidrocarbonetos em praticamente todas as configurações de modelo. Calculamos os resultados considerando variações na profundidade do mar, na posição dos receptores e na resistividade da camada de hidrocarbonetos. Observamos a influência da airwave, presente mesmo em profundidades oceânicas com mais de 1000m, e apesar de não ser possível uma simples separação dessa influência nos dados, o domínio do tempo nos permitiu fazer uma análise de seus efeitos sobre o levantamento. Como parte da preparação para a modelagem em ambientes 2D e 3D, fazemos também um estudo sobre o ganho de desempenho pelo uso do paralelismo computacional em nossa tarefa.

Seismic modelling and ava analysis of hidrocarbon traps

In this study, forward seismic modelling of four geological models with Hydrocarbon (HC) traps were performed by ray tracing method to produce synthetic seismogram of each model. The idea is to identify the Hydrocarbon Indicators (HCI‟s) such as bright spot, flat spot, dim spot and Bottom Simulating Reflector (BSR) in the synthethic seismogram. The modelling was performed in DISCO/FOCUS 5.0 seismic data processing programme. Strong positive and negative reflection amplitudes and some artifact reflection horizons were observed on produced seismograms due to rapid changes in subsurface velocity and geometry respectively Additionally, Amplitude-versus-angle (AVA) curves of each HCIs was calculated by the Crewes Zoeppritz Explorer programme. AVA curves show that how the reflection coefficients change with the density and the P and S wave velocities of each layer such as oil, gas, gas hydrate or water saturated sediments. Due to AVA curves, an increase in reflection amplitude with incident angle of seismic waves corresponds to an indicator of a hydrocarbon reservoir

Seismic characteristics of a reef carbonate reservoir and implications for hydrocarbon exploration in deepwater of the Qiongdongnan Basin, northern South China Sea

Our analysis of approximately 40,000 km of multichannel 2-D seismic data, reef oil-field seismic data, and data from several boreholes led to the identification of two areas of reef carbonate reservoirs in deepwater areas (water depth >= 500 in) of the Qiongdongnan Basin (QDNB), northern South China Sea. High-resolution sequence stratigraphic analysis revealed that the transgressive and highstand system tracts of the mid-Miocene Meishan Formation in the Beijiao and Ledong-Lingshui Depressions developed reef carbonates. The seismic features of the reef carbonates in these two areas include chaotic bedding, intermittent internal reflections, chaotic or blank reflections, mounded reflections, and apparent amplitude anomalies, similar to the seismic characteristics of the LH11-1 reef reservoir in the Dongsha Uplift and Island Reef of the Salawati Basin, Indonesia, which house large oil fields. The impedance values of reefs in the Beijiao and Ledong-Lingshui Depressions are 8000-9000 g/cc x m/s. Impedance sections reveal that the impedance of the LH11-1 reef reservoir in the northern South China Sea is 800010000 g/cc x m/s, whereas that of pure limestone in BD23-1-1 is > 10000 g/cc x m/s. The mid-Miocene paleogeography of the Beijiao Depression was dominated by offshore and neritic environments, with only part of the southern Beijiao uplift emergent at that time. The input of terrigenous sediments was relatively minor in this area, meaning that terrigenous source areas were insignificant in terms of the Beijiao Depression: reef carbonates were probably widely distributed throughout the depression, as with the Ledong-Lingshui Depression. The combined geological and geophysical data indicate that shelf margin atolls were well developed in the Beijiao Depression, as in the Ledong-Lingshui Depression where small-scale patch or pinnacle reefs developed. These reef carbonates are promising reservoirs, representing important targets for deepwater hydrocarbon exploration. (C) 2008 Elsevier Ltd. All rights reserved.

Acoustic and petrophysical relationships in low-shale sandstone reservoir rocks

This paper describes the measurements of the acoustic and petrophysical properties of two suites of low-shale sandstone samples from North Sea hydrocarbon reservoirs, under simulated reservoir conditions. The acoustic velocities and quality factors of the samples, saturated with different pore fluids (brine, dead oil and kerosene), were measured at a frequency of about 0.8 MHz and over a range of pressures from 5 MPa to 40 MPa. The compressional-wave velocity is strongly correlated with the shear-wave velocity in this suite of rocks. The ratio V-P/V-S varies significantly with change of both pore-fluid type and differential pressure, confirming the usefulness of this parameter for seismic monitoring of producing reservoirs. The results of quality factor measurements were compared with predictions from Biot-flow and squirt-flow loss mechanisms. The results suggested that the dominating loss in these samples is due to squirt-flow of fluid between the pores of various geometries. The contribution of the Biot-flow loss mechanism to the total loss is negligible. The compressional-wave quality factor was shown to be inversely correlated with rock permeability, suggesting the possibility of using attenuation as a permeability indicator tool in low-shale, high-porosity sandstone reservoirs.

Reservoir characterization of the Cardium Formation in the Ferrier Oilfield, west-central Alberta, Canada.

This thesis has the main aim of defining the lithostratigraphy, depositional architecture, post-depositional modifications and reservoir characteristics of the Cardium Formation in the Ferrier Oilfield, and how these characteristics can have great impact over production rates, GOR and produced fluid discrimination. In the Ferrier area, the Cardium Formation is composed by a NE prograding clastic sequence made up of offshore to shoreface deposits sealed by marine shales. The main reservoir is composed by sandstones and conglomerates interpreted to have deposited in a shoreface depositional environment. Lithofacies and net reservoir thickness mapping led to more detailed understanding of the 3D reservoir architecture, and cross-sections shed light on the Cardium depositional architecture and post-deposition sediment erosion in the Ferrier area. Detailed core logging, thin section, SEM and CL analyses were used to study the mineralogy, texture and pore characterization of the Cardium reservoir, and three main compartments have been identified based on production data and reservoir characteristics. Finally, two situations showing odd production behaviour of the Cardium were resolved. This shed light on the effect of structural features and reservoir quality and thickness over hydrocarbon migration pathways. The Ferrier example offers a unique case of fluid discrimination in clastic reservoirs due both to depositional and post-depositional factors, and could be used as analogue for similar situations in the Western Canadian Sedimentary Basin.