Structural Investigation for Locating Petroleum Reservoirs Using Geoinformatics in Meyal, Potwar Region, Pakistan

Reflection Seismology technique (Seismic Survey) is widely used around the world to produce a detailed analogue image of subsurface geological structures. This information is used by petroleum experts to accurately plan the location of oil wells. Seismic survey sections and corresponding well logs exhibit different variables like acoustic impedance of rock, seismic velocity, rock density, porosity, time and depth that can be manipulated in GIS to infer a subsurface model for stratigraphic as well as structural interpretations. In recent years, GIS has emerged as a powerful analytical tool for subsurface mapping and analysis. Petroleum exploration is a map intensive process that requires the powerful capabilities of GIS. Purpose of this research is integration of Geographical Information System with Seismic Surveys for Structural and Stratigraphic Interpretation of subsurface Geology and locating Petroleum Prospects. In this research work, GIS has been used to investigate subsurface geological structures and stratigraphy to carefully analyze the capabilities of GIS for finding new petroleum prospects in active thrust belt of Meyal, Potwar region, Pakistan. Acquisition of two-dip and three-strike seismic lines is along with well log data, followed by spatial seismic data processing, development of geophysical data management interface, interpolation of shot point data, trend surface analysis and Geostatistical analysis using GIS. Subsurface zones of high, low or null probability of petroleum accumulation were then, mapped. Finally, GIS based maps were developed. Geospatial tomography GIS model inferred that study area is structurally deformed and exhibits excessive geological faults, and structural traps. With GIS-tomography interpretation of section 97-MYL-08, a potential oil bearing zone (popup anticline), bounded by two thrust faults was observed at almost 3.6 Km depth in Meyal area with average density of about 2.6 gm/cm3. Thrust fault recognized from sharp discontinuity in GIS based survey raster was encountered at 2.9 Km depth. Structure contour map was developed. It depicted that Chorgali formation (dolomitic limestone) at 3.68 Km depth was proven to be reservoir rock in study area. GIS has proved to be a powerful and efficient subsurface modeling and analytical tool and it should be integrated with survey based studies for exploration of oil and gas and investigation of subsurface geological structures.

Phase-Controlled and Gas-Washing Fractionations During the Formation of Petroleum Reservoirs

By PVT fractionation experiments to model phase\|controlled and gas\|washing fractionations during the formation of petroleum reservoirs, the authors measured the physical and chemical properties of products formed in different fractionation stages and made a correlative analysis of the influence of depressurization and gas washing on oil/gas molecular composition and the rule of fractionation. The analytical results showed that gas washing is an important factor affecting the physical properties of crude oils, and also can be regarded as a good genetic interpretation of marine wax\|high oils in the Tarim region, Xinjiang, China. Phase\|controlled and gas\|washing fractionations can lead to the formation of condensates and their differences in chemical composition from crude oils are a direct reflection of evaporating fractionation. Phase\|controlled and gas\|washing fractionations have a great influence on the composition of molecular compounds and relevant parameters. So phase\|controlled and gas\|washing fractionations during the formation of petroleum reservoirs are not only favorable to identifying different processes of formation of petroleum reservoirs, but also to the scientific application of routine geochemical parameters.

Evaluating reservoir suitability for large-scale hydrogen storage:A preliminary assessment considering reservoir properties

With rising demand for clean energy,global focus turns to finding ideal sites for large-scale underground hydrogen storage(UHS)in depleted petroleum reservoirs.A thorough preliminary reservoir evaluation before hydrogen(H_(2))injection is crucial for UHS success and safety.Recent criteria for UHS often emphasize economics and chemistry,neglecting key reservoir attributes.This study introduces a comprehensive framework for the reservoir-scale preliminary assessment,specifically tailored for long-term H_(2) storage within depleted gas reservoirs.The evaluation criteria encompass critical components,including reservoir geometry,petrophysical properties,tectonics,and formation fluids.To illustrate the practical application of this approach,we assess the Barnett shale play reservoir parameters.The assessment unfolds through three key stages:(1)A systematic evaluation of the reservoir's properties against our comprehensive screening criteria determines its suitability for H_(2) storage.(2)Using both homogeneous and multilayered gas reservoir models,we explore the feasibility and efficiency of H_(2) storage.This phase involves an in-depth examination of reservoir behavior during the injection stage.(3)To enhance understanding of UHS performance,sensitivity analyses investigate the impact of varying reservoir dimensions and injection/production pressures.The findings reveal the following:(a)Despite potential challenges associated with reservoir compaction and aquifer support,the reservoir exhibits substantial promise as an H_(2) storage site.(b)Notably,a pronounced increase in reservoir pressure manifests during the injection stage,particularly in homogeneous reservoirs.(c)Furthermore,optimizing injection-extraction cycle efficiency can be achieved by augmenting reservoir dimensions while maintaining a consistent thickness.To ensure a smooth transition to implementation,further comprehensive investigations are advised,including experimental and numerical studies to address injectivity concerns and explore storage site development.This evaluation framework is a valuable tool for assessing the potential of depleted gas reservoirs for large-scale hydrogen storage,advancing global eco-friendly energy systems.

Large scale petroleum reservoir simulation and parallel preconditioning algorithms research

Solving large scale linear systems efficiently plays an important role in a petroleum reservoir simulator, and the key part is how to choose an effective parallel preconditioner. Properly choosing a good preconditioner has been beyond the pure algebraic field. An integrated preconditioner should include such components as physical background, characteristics of PDE mathematical model, nonlinear solving method, linear solving algorithm, domain decomposition and parallel computation. We first discuss some parallel preconditioning techniques, and then construct an integrated preconditioner, which is based on large scale distributed parallel processing, and reservoir simulation-oriented. The infrastructure of this preconditioner contains such famous preconditioning construction techniques as coarse grid correction, constraint residual correction and subspace projection correction. We essentially use multi-step means to integrate totally eight types of preconditioning components in order to give out the final preconditioner. Million-grid cell scale industrial reservoir data were tested on native high performance computers. Numerical statistics and analyses show that this preconditioner achieves satisfying parallel efficiency and acceleration effect.

Comprehensive analysis of CBM recovery in high rank coal reservoir of Jincheng area

Coalbed methane (CBM) predicting recovery in high rank coal reservoir varies greatly in Jincheng area and it seriously influences efficient and economic exploitation of CBM resource. In order to predict more accurate CBM recovery, we conducted history matching and productivity prediction of vertical well by using COMET 3 reservoir modeling software, innovatively adopted the gas desorption experiment of bulk coal at fixed test pressure, analyzed the recovery extent method of Daning multiple-hole horizontal well and Panzhuang well group, and calculated recovery by sorption isotherm method of 14 vertical CBM wells at the abandonment pressures 1.0, 0.7, 0.5 and 0.3 MPa, respectively. The results show that the reservoir simulation methods (numerical simulation method and the recovery extent method) is more reliable than the theoretical analysis of coal sample (sorption isotherm method and desorption experiment method). Also, desorption experiment method at fixed pressure is superior to sorption isotherm method. Through the comprehensive analysis and linear correction, CBM recovery ratios in high rank coal reservoir of Jincheng area were found to be 38.64%, 49.30%, 59.30%, and 69.20% at the abandonment pressures 1.0, 0.7, 0.5 and 0.3 MPa, respectively. The research results are of significant importance in the CBM exploration and development in Jincheng area.

Development of re-crosslinkable dispersed particle gels for conformance improvement in extremely high-temperature reservoirs

Micro-scale and nano-scale dispersed gel particles(DPG)are capable of deep migration in oil reservoirs due to their deformability,viscoelasticity,and suitable particle size.Therefore,it has been widely studied and applied in reservoir conformance control in recent years.However,for highly permeable channels,their plugging performance is still limited.In addition,conventional in situ cross-linked polymer gels(ISCPGs)have fast gelation time under extremely high-temperature conditions,which often causes problems such as difficulty in pumping.Therefore,a re-cross linkable dispersed particle gel(RDPG)system applied for conformance control in highly permeable channels of extremely high-temperature petroleum reservoirs was investigated.The particle size distribution,gelation time,gel strength,injection performance,and perfo rmance strength in po rous media were investigated using a laser particle size meter,the Sydansk bottle test method,rheometer,and core displacement experiments,respectively.Results show that the RDPG suspension can be stable for more than 6 months at room temperature with storage modulus G’much lower than 10 Pa.It can pass through the pore throat by elastic deformation effect and does not cause strong blockage.Moreover,it can undergo re-crosslinking reaction at 150℃to form a strong bulk gel.The gel strength G’of re-crosslinked RDPG can be as high as 69.3 Pa,which meets the strength requirement of conformance control.The RDPG suspension has the properties of easy injection,and it also has strong plugging,and high-temperature resistance after re-crosslinked in the core,which can be a very promising material for conformance improvement in extremely high-temperature reservoirs.

Logging Geology Study of the Caverned Paleokarst Reservoir Distribution

In recent years, many carbonate rock oilfields such as Lunnan and Tahe have been found in the Tarim Basin, and the main reservoir space of the stable high yield wells in these oilfields consists mainly of the caverns formed by the paleo-karstification and the dissolution pores and fractures connected with them. Nevertheless, it is difficult to predict effectively the distribution of the cavern reservoir because of its extremely serious heterogeneity. In this paper, a case study of the Lunxi Oilfield in the north uplift of the Tarim Basin is conducted to introduce the logging geology method for predicting the distribution of the caverned paleokarst reservoir. By means of building up the logging recognition style of different caverns and differentiating and correlating the karst zones with logging curves, and through an analysis of the paleokarst topography background, the favorable karst zones and distribution areas of the high quality cavern reservoir have been located, which lays a new basis for further exploration in this area.

塔里木盆地三大构造旋回油气成藏特征

塔里木盆地形成经历了南华纪—中泥盆世、晚泥盆世—三叠纪和侏罗纪—第四纪3大伸展-挤压构造旋回,其多旋回构造演化导致油气成藏和分布十分复杂。随着近年来盆地超深层已经成为油田的重点勘探领域,有必要对盆地的油气成藏规律进行深入探讨。本文基于最新的地震资料、钻井资料及油气地质资料,发现塔里木盆地油气规模成藏主力烃源岩为库车地区三叠系—侏罗系及塔西南地区石炭系—二叠系陆相烃源岩、台盆区寒武系海相烃源岩。盆内烃源岩及储盖组合的发育均受控于盆地3大伸展-挤压构造旋回,烃源岩的发育位置决定了塔里木盆地发育库车山前、北部坳陷、麦盖提斜坡及塔西南山前四大含油气系统。盆地在历经3大伸展-挤压旋回,其台盆区、库车前陆及塔西南前陆地区油气成藏组合差异大。台盆区发育石炭系膏泥岩与志留系—石炭系海相砂岩、奥陶系泥岩与灰岩、中寒武统膏盐岩与震旦系—寒武系白云岩储盖组合;库车地区发育新近系—第四系泥岩与砂岩、古近系膏盐层与白垩系砂岩、侏罗系泥岩与三叠系—侏罗系砂岩储盖组合;塔西南地区发育中新统泥岩-砂岩、古近系膏盐层与白垩系砂岩、石炭系—二叠系泥岩与碳酸盐岩储盖组合,分别组成了台盆区、库车及塔西南地区的上部、中部及下部组合。盆内烃源岩在加里东晚期、海西晚期—印支期、喜山期发生排烃,形成三期油气充注,结合塔里木盆地关键变革期的岩性、断裂、不整合及隆起的发育特征,构建了盆地三期成藏模式。

BTEX anomalies used as indicators of submarine oil and gas reservoirs

It is a conventional method for petroleum prospecting to generally use paraffin hydrocarbon as basic indexes of oil and gas. This conventional geochemical technology, however, shows some limits in the prospecting as paraffin is vulnerable to influences from human and biologic activities. Consequently, BTEX （short for benzene, toluene, ethyl benzene and xylem, which are direct biomarkers） among aromatic hydrocarbon series has been taken into account for the oil and gas prediction. Domestic and foreign study results demonstrate that BTEX is hardly disturbed and can well indicate oil and gas reservoirs. Based on measured data from a South China Sea area, the present authors have used self-developed visual assessment software for petroleum prospecting has been used to process data, strip background anomalies, and outline significant BTEX anomalies. By comparison with stratigraphic profiles of the target area, it is confirmed that BTEX is a good indication of marine oil and gas during the petroleum prospecting.

Petroleum systems of the Taoudeni Basin,West Africa

The Taoudeni Basin is a typical steady intracratonic basin. Based on the distribution of effective source rocks in the Taoudeni Basin, combined with the structure characteristics of the basin and the distribution characteristics of reservoir beds, two petroleum systems are recognized in the basin： the infra-Cambrian petroleum system and the Silurian petroleum system. Structural uplift and timing of petroleum generation controlled the timing of petroleum charging and preservation of hydrocarbon accumulations. Maturity, evolution history, and distribution of effective source rocks controlled hydrocarbon richness. The geological key factors and geological processes controlled the type of hydrocarbon accumulations.

Subvolcanic Rock Petroleum System Potential in the South Malang Region, East Java, Indonesia

The South Malang Region is located in the south-eastern part of the Southern Mountain Volcanic Arc;it presents different opportunities for hydrocarbon exploration. The stratigraphy of the study area from old to young consists of Oligocene Volcanic rocks (Mandalika, Watupatok, and Arjosari Formation), Early Miocene Carbonates (Campurdarat and Jaten Formation), Middle Miocene Volcanic (Wuni Formation), Late Miocene-Pliocene Carbonates (Nampol, Oyo, and Wonosari Formation), and Holocene alluvial deposits (Kalipucang Formation). The dominance of volcanic rocks makes this area considered an area without hydrocarbon play prospects. Petroleum system potential is revealed by evaluating and analyzing potential source rock and reservoir rock outcrop samples. The study shows that the Nampol Formation can be considered as a gas-prone source rock, with type III kerogen, total organic content ranging from 3.48 - 26.18 wt%, and possess the potential to produce good to very good hydrocarbons and a hydrogen index ranging from 43 to 86 mgHC/g TOC. Furthermore, rock core analysis and petrographic studies were carried out on the Nampol sandstone where the rock samples showed good reservoir properties. However, the Nampol and Wonosari limestone that was considered as the secondary target for reservoir possesses a low quality of reservoir properties. This study shows that there is a potential for petroleum system existence in the Southern Mountain subvolcanic arc, which is indicated by the presence of source rock and potential reservoir rock as one of the various elements and processes present in a petroleum system.

Petroleum Exploration Prospects in Erlian Basin,China

Ertian Basin is located in the middlc prairie.Inner M ongolia A utonomous.Region.the north border of China.Tectonically.Erlian Basin is to thc south of Bayinbaoligel Uplift and the north is the Wendouer Temple Uplift.In the east of the basin.there is Daxinganling Uplift and the west is Soulunshan Uplift.The basin covered an area of 100000 km'.is a Mesozoic-Cenozoic graben(rift)basin that cvolved on the folded basement of Hercvnian geosyncline.

Sedimentology and Ichnology of Upper Montney Formation Tight Gas Reservoir, Northeastern British Columbia, Western Canada Sedimentary Basin

Several decades of conventional oil and gas production in Western Canada Sedimentary Basin (WCSB) have resulted in maturity of the basin, and attention is shifting to alternative hydrocarbon reservoir system, such as tight gas reservoir of the Montney Formation, which consists of siltstone with subordinate interlaminated very fine-grained sandstone. The Montney Formation resource play is one of Canada’s prime unconventional hydrocarbon reservoir, with reserve estimate in British Columbia (Natural Gas reserve = 271 TCF), Liquefied Natural Gas (LNG = 12,647 million barrels), and oil reserve (29 million barrels). Based on sedimentological and ichnological criteria, five lithofacies associations were identified in the study interval: Lithofacies F-1 (organic rich, wavy to parallel laminated, black colored siltstone);Lithofacies F-2 (very fine-grained sandstone interbedded with siltstone);Lithofacies F-3A (bioturbated silty-sandstone attributed to the Skolithos ichnofacies);Lithofacies F-3B (bioturbated siltstone attributed to Cruziana ichnofacies);Lithofacies F-4 (dolomitic, very fine-grained sandstone);and Lithofacies F-5 (massive siltstone). The depositional environments interpreted for the Montney Formation in the study area are lower shoreface through proximal offshore to distal offshore settings. Rock-Eval data (hydrogen Index and Oxygen Index) shows that Montney sediments contains mostly gas prone Type III/IV with subordinate Type II kerogen, TOC ranges from 0.39 - 3.54 wt% with a rare spike of 10.9 wt% TOC along the Montney/Doig boundary. Vitrinite reflectance data and Tmax show that thermal maturity of the Montney Formation is in the realm of “peak gas” generation window. Despite the economic significance of the Montney unconventional “resource-play”, however, the location and predictability of the best reservoir interval remain conjectural in part because the lithologic variability of the optimum reservoir lithologies has not been adequately characterized. This study presents lithofacies and ichnofacies analyses of the Montney Formation coupled with Rock-Eval geochemistry to interpret the sedimentology, ichnology, and reservoir potential of the Montney Formation tight gas reservoir in Fort St. John study area (T86N, R23W and T74N, R13W), northeastern British Columbia, western Canada.

微生物提高油藏原油采收率进展

文章从油藏中普遍存在的采油微生物类群及其驱油机制、微生物采油技术的矿场应用、采油微生物的响应等方面对油藏微生物及其提高原油采收率进展进行综述.同时从营养剂在油藏储层中的分布、油藏环境下微生物生长代谢活性、油藏微生物定向调控等方面阐述了微生物采油技术发展的基础问题.

Methods in Oil Recovery Processes and Reservoir Simulation

The exploitation of an oil field is a complex and multidisciplinary task, which demands a lot of prior knowledge, time, and money. A good reservoir characterization is deemed essential in the accomplishment of Enhanced Oil Recovery (EOR) processes in order to estimate accurately the properties of the porous medium affecting the flow properties. Several techniques at a field scale are currently being used to determine these properties, which are time and money consuming. But these alone do not guarantee the success of the project. Reservoir simulation and numerical techniques were then included in the pre-development and follow-up studies as an effective tool to determine the productivity and future behavior of the oil field. As the computational power increased, more advanced and detailed models were developed, including different chemical and physical phenomena. But alongside this process, there was an active research in the area of reservoir simulation, improving the accuracy and efficiency of the numerical schemes used for the flow, transport, and energy equations. The aim of this review is to address the topics described. Firstly, the origin of an oil recovery process, the economic factors and field tests involved are introduced. Secondly, the oil and porous medium origin and characterization as well as an introduction to the fundamental concepts and equations are associated to reservoir simulation. Finally, a brief description and analysis of the techniques are used in reservoir simulation employing finite difference methods, their downsides and possible ways to overcome these problems.

Corrosion and Scaling Threat in Upstream Oil Operation

Corrosiveness or scaling is an inherent threat to oil operations. The primary cause for this threat is the presence of water having complex geochemical matrix. Unanticipated water production, particularly if it contains unwanted impurities, can significantly impact hydrocarbon production. The current paper discusses the degree of threat posed to oil operation facilities based on the water characteristics. Methodology involved the collection and analysis of water samples from major sources in oil industry such as groundwater, wellheads and seawater. The parameters tested include geochemical, microbiological and pollutants. The lab data was used to develop scaling and corrosion prediction indices such as Langelier Saturation Index (LSI), Ryznar Stability Index (RSI) and Puckorius Scaling Index (PSI). The study indicated varying water chemistry for different sources. Mixing of those waters may lead to ionic saturation and scaling in different facilities. Presence of the SRB and GAB in some water sources also posed threat to water system by forming fouling and corrosion. Seawater used for offshore oilfields water injection to maintain reservoir pressure and improve oil recovery showed scaling tendency, whereas under different reservoir pressure, it can cause corrosion. Some of the samples also had corrosion residuals such as iron, which indicated active corrosion. Current study showed higher alkalinity with high sulfate for one groundwater sample with presence of active corrosion residuals such as dissolved iron and manganese. The study showed positive value for LSI which indicated supersaturation of the water samples with respect to calcium carbonate (CaCO3) and scale forming. Similarly, for RSI and PSI, the value was below six which confirmed the scaling potential for all the samples. Even though the index value was pointing towards scaling potential, the geochemistry, microbiology and presence of other impurities indicated corrosion threat to the oil and gas industrial facilities. The study concluded the importance of different scale inhibition mechanism and corrosion control in Oil and Gas industry.

耐盐型阴/阳离子表面活性剂高效渗吸体系构筑及性能评价

针对长庆安塞油田油藏条件,构建了阴离子表活剂APGSHS和双十八烷基阳离子表活剂复配的耐盐型高效渗吸体系。在矿化度为74.11 g·L^(-1)、温度为50℃的条件下,通过界面张力优选出适合该油田的最佳渗吸体系,并研究了该渗吸体系的润湿性能、乳化性能以及渗吸采油效果。结果表明:复配体系可将油水界面张力维持在10^(-3)mN·m^(-1)数量级;同时,该体系具有优异的润湿反转能力以及较佳的乳化性能,该复配体系针对0.3~30.0 mD的岩心渗吸采收率可达40%以上。

鄂尔多斯盆地西部古峰庄地区三叠系延长组裂缝特征及其对低渗透油藏的控制作用

[研究目的]鄂尔多斯盆地西部古峰庄地区三叠系延长组属于低渗透储层,天然裂缝较为发育,以往对裂缝特征研究较少,开展天然裂缝特征和形成时期研究对低渗透油藏勘探开发具有重要作用。[研究方法]文章通过野外露头、钻井岩心、成像测井、扫描电镜裂缝识别和流体包裹体、断裂活动、构造应力分析等方法展开了古峰庄地区延长组天然裂缝特征和控藏作用研究。[研究结果]延长组各段天然裂缝均发育,以长7段最为发育,其次为长8、长6段;裂缝以高角度裂缝和垂直裂缝为主,走向以NEE向为主,NE向次之,少量NW和NWW向;裂缝面可见方解石充填和明显过油痕迹。天然裂缝发育程度与岩层厚度、断裂活动密切相关。裂缝形成时期具有多期性,主要为燕山期和喜马拉雅期。[结论]延长组天然裂缝的发育改善了研究区低渗透储层的孔渗能力和储集空间,为低渗透油藏运移、储集和富集提供了良好条件,其发育程度与形成时期影响着低渗透油藏的成藏和产能。

塔里木盆地东南缘瓦石峡凹陷山前地区侏罗系烃源岩特征及油气地质意义

瓦石峡凹陷主要发育侏罗系康苏组、杨叶组烃源岩。通过地表调查、样品分析测试对侏罗系烃源岩的分布、厚度变化规律及有机地球化学特征研究,结合前人成果资料,初步评价油气资源潜力。侏罗系烃源岩累计厚度最大563.8 m。康苏组烃源岩累计厚度88.1 m,TOC为0.66%~38.3%,干酪根主要为Ⅱ2和Ⅲ型,Ro为0.42%~0.95%,以低成熟-成熟为主;杨叶组为主力烃源岩,累计厚度最大328 m,TOC为0.21%~55.23%,干酪根主要为Ⅱ2和Ⅲ型,少量Ⅰ型,Ro为0.44%~1.96%,以成熟为主,部分达高成熟。研究区烃源岩分布广、厚度大、有机质丰度高、成熟度适中,主要为好-优质烃源岩,达生油气阶段,生烃潜力较大,具良好的油气勘探前景。

杭锦旗地区二叠系储层油气成藏期次及流体势特征

杭锦旗地区是鄂尔多斯盆地北部重要的含油气区,油气成藏期次及流体势研究有利于探究油气充注的世代以及流体势的分布特征,并进一步判定成藏期油气的运移方向。本文以什股壕区块和十里加汗区块5口井的二叠系下石盒子组盒一段储层砂岩为研究对象,基于流体包裹体分析厘定油气成藏期次,并结合流体势理论计算研究区关键成藏期的流体势并揭示油气的运移方向。研究结果显示:什股壕区块盒一段储层油气的成藏时间为132~102 Ma;十里加汗区块盒一段储层油气的成藏时间为132~101 Ma。杭锦旗北部的什股壕盒一段储层油气的流体势为18 128~22 872 J/kg;杭锦旗南部的十里加汗区块盒一段储层油气的流体势为22 975~27 153 J/kg。本文认为研究区二叠系盒一段储层油气成藏时间在早白垩世,十里加汗区块整体的流体势要高于什股壕区块,油气具备由南部向北部运移的趋势。