Day 3 Wed, October 23, 2019最新文献

{"title":"EPC Strategies for a Successful Project Execution","authors":"Mohamed Saeed AlMarar","doi":"10.2118/198578-ms","DOIUrl":"https://doi.org/10.2118/198578-ms","url":null,"abstract":"\u0000 The essential requirements for sanctioning Energy Sector projects have always been conceptual planning, Front-End Engineering Design (FEED) and feasibility studies. Traditional EPC projects start with a planning phase, a design phase, a construction phase, a testing phase, and a turnover to the user phase followed by project closeout. Such projects are usually delivered through water fall management approach. Large EPC projects have more elaborate models with multiple stage gates and bid phases, but the commonality is the sequential nature, with user input happening primarily in the planning and or design phase. During construction phase again there is a sequential work plan with defined project schedule defining activities with regards to trade or geographic areas. Large construction projects are usually implemented through multiple sub-contractors under a general contractor, with a separate designer and a separate owner, and in some cases separate end users (tenants), with complex contracting methodology (ies) in place.\u0000 As the era of \"easy hydrocarbons\" is approaching its end, mega-projects are becoming a norm in petroleum sector despite high CAPEX and having long lead times for reaching commercial operations. This is so because unconventional oil and gas like shale gas, Oil sands, FLNG, Ultra-deep water reservoirs require implemetation of state-of-the-art technologies and resource in lesser known project site conditions. FID for such project has traditionally been based on conceptual planning, Front-End Engineering Design (FEED) and feasibility studies. These preliminary steps also help in defining a rigid process (Stage Gate Process \"SGP\") to follow during subsequent project progress related to EPC activities. SGP outlines activities to be completed in every stage of the project and progress into subsequent stage is authorized only with the approval of a committee / individual called \"Gatekeeper\".\u0000 This study discusses application of SGP, having shared Gatekeeper from project stakeholders, together with Agile project management methods, SCRUM to be specific, for developing successful strategies for project EPC phase.\u0000 As oil and gas industry is moving to megaprojects with innovative reserves recovery ideas, the sector is experiencing increased utility of Agile project-management methods. The entire innovation process has great potential in reducing project development time frame and increasing the success rate of Greenfield or Brownfield projects. This study outlines how Agile method, such as Scrum, can be used as a structured innovative methodology with milestones and decision points (similar to Stage-Gate), and benefits for project stakeholders. This study is carried out as follows: One (01) Green Field project is selected for investigation related to successful EPC management through possible use of Scrum (Agile Methodology)One (01) IT Project is selected for investigations related to successful implementation of Agile management during","PeriodicalId":182237,"journal":{"name":"Day 3 Wed, October 23, 2019","volume":"52 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115021122","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Understanding O/G Shale Reservoir Tortuosity by Imaging Characterizations","authors":"Mohammad Sewailan, W. Al-Bazzaz","doi":"10.2118/198659-ms","DOIUrl":"https://doi.org/10.2118/198659-ms","url":null,"abstract":"\u0000 A shale reservoir rock sample has been imaged successfully at 40X (millimeter scale), 400X (micrometer scale), and 4000X (nanometer scale). All captured images have been processed with morphological approach utilizing big data for porosity with pore size distribution as well as tortuosity. 1D, 2D and 3D pre-logic models are developed. And heterogeneity post-logic models are also developed. Nano pores are dominated in shale rock; as a result, the tortuous paths recognized are very complex yet very hopeful for many production scenarios.\u0000 The prepared shale rock samples in the form of rock fragments will be imaged and characterized for porosity morphology, pore size distributions, and tortuosity in 2D format utilizing SEM-BSE imaging techniques. The generated images will be quantified using pre-defined logic (10-classes of pore ranges, pore counts, pore frequency percent, and pore area). The data generated will be used to estimate tortuosity. Tortuosity investigations are set for different magnifications X40-millimeter scale, X400-micrometer scale, and X4000-nanometer scale, yielding the total formation/ sample experiments to become 3 magnifications X 1 sample = 3 experiment suites to ensure tortuosity representations for all shale pore magnification.\u0000 The overall objective is to increase shale reservoir knowledge and awareness of imaging characterizations that inherits increasingly sophisticated and unconventional technologies, which make the production of unconventional resources faster, accurate, and economically efficient. Another objective is to justify the exploitation of organically rich unconventional Oil and Gas (O&G) shale reservoirs that were always ignored by operators seeking easier production and faster returns on investments, as potential sources of significant natural gas and liquid reserves. The final objective is to introduce a reliable method to quantify tortuosity for unconventional reservoirs that seeks new physics in order to advance stimulation, advance reservoir characterization, and advance recovery efficiencies and production improvement.","PeriodicalId":182237,"journal":{"name":"Day 3 Wed, October 23, 2019","volume":"52 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117029342","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"WFT Applications Experience in the Challenging Geologic Conditions of a Caspian Sea Brownfield to Increase Development and Production Efficiency","authors":"V. Blinov, M. Hashem, Zhandos Zhangaziyev, M. Binbrek, M. Gibrata, S. Ghedan, M. Charupa, Samat Ramatullaev, M. Zeybek","doi":"10.2118/198550-ms","DOIUrl":"https://doi.org/10.2118/198550-ms","url":null,"abstract":"\u0000 Wireline Formation Tester (WFT) technologies are well known in oil field industry as a major crucial answers provider for formation evaluation especially during appraisal and exploration stages. Meanwhile, their applications are also very useful in the development period of complex brownfields such in the Caspian Sea offshore Turkmenistan to optimize production and increase cost-efficiency. The main challenges caused by geologic conditions including but are not limited as following: multi-layered sandstones with different hydrocarbons types (gas, gas condensate, oil) masked by shales, varying depletion due to heterogeneity and reservoir connectivity uncertainties, some of formations has a low H2S content, increasing water production, gas breakthrough and wax deposition.\u0000 WFT provides current pressure measurements and this is important parameter for completion strategy as it defines perforation intervals, packer setting depths and type of screens for reservoir production inflow profile management. Multiwell analyses of pressures survey complimented by reservoir fluids geodynamic study are affording understanding about reservoir connectivity. Downhole fluid analysis allows to get in real-time information about reservoir saturation with formation fluids typing to control in future undesirable gas and water increasing issues. In order to qualify and quantify the wax related issues and manage them in flow assurance workflow laboratory test should be carried out on PVT sample acquired at reservoir conditions. H2S presence is varying across the field and identifying potentially soured layers is required special sampling technique to confirm and exclude them from production. More advanced WFT application such as pressure transient and vertical interference tests provide in situ measurements of effective permeabilities with anisotropy magnitude.\u0000 Modern WFT tools were run for years on Djeitun (LAM) and Dzhigalybeg (Zhdanov) fields for production and flow assurance optimization purposes and main applications of this technologies will be discussed here. The benefits of pinpoint pressure measurements and subsequent gradient analysis are vital for analyzing reservoir connectivity. Real time fluid analysis with laboratory accuracy and a wide variety of packer and probe interfaces allow the acquisition of valuable fluid data and representative fluid samples down to quite low permeabilities with preserving reservoir conditions and capturing even extremely low H2S content. Also, years of pressure transient experience has been transported to the WFT environment enabling to derive a rich dataset of permeability what can be used to estimate interval productivity index. Cased hole WFT application allows to obtain information about fluid and reservoir properties in conditions where it was previously impossible in open hole due to technical or geological constraints.","PeriodicalId":182237,"journal":{"name":"Day 3 Wed, October 23, 2019","volume":"24 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114189580","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Maximizing Oil Recovery Through Hybrid Smartwater Surface Active Polymer: A Novel Environomic EOR Technology","authors":"M. Haroun, Motiur Rahman, Yao Li, Cheng-yang Jiang, S. Ghedan, Joost de Bakker, Yongfu Wu","doi":"10.2118/198557-ms","DOIUrl":"https://doi.org/10.2118/198557-ms","url":null,"abstract":"\u0000 This study aims to develop a novel technology using in-house surface-active polymer (SAP) developed for enhanced oil recovery (EOR) by improving in-situ conformance controlling via self-adaptive viscofication and surface wettability. This study combines the preconditioning capability of smart water and the volumetric sweep efficiency improvement of polymer flooding. The success of this study could lead to an advanced EOR process, applicable specifically under complex reservoir field conditions.\u0000 For decades, numerous studies have been attempted to address recovery issues through a single EOR technique. Among these studies, smart water flooding (SWF) has demonstrated potential in increasing oil recovery through wettability alteration, especially for complex reservoir conditions, such as reservoirs with high clay content and high heterogeneity. The key innovation of this investigation is to incorporate cost-effective, surface active polymeric system with SWF to further improve oil recovery efficiency. As opposed to regular polymers and fluid diverting agents, such a surface-active polymeric system with a distinct behavior termed as \"Self-Adaptive Thickening\" can increase the aqueous phase viscosity at high shear rate thereby lowering the water-oil mobility ratio. It can also selectively seal-off (long term or temporary) a thief layer or a channel to divert water to relatively low-permeability oil-rich zones. SWF works in tandem with the surface-active polymeric system to reduce the residual oil saturation by altering reservoir wettability, therefore increasing the displacement efficiency of the process.\u0000 Multiple engineered brines were analyzed, prepared, and selected as preconditioning fluids. The tested coreplugs were flooded with the selected engineered brines combined with the different types of polymers to establish impact on recovery. This involved screening and short-listing multiple combinations of Hybrid SWF SAP (HSWFSAP) samples. These shortlisted formulations were further tested under reservoir pressure, temperature, oil saturation and wettability conditions. Coreplugs were saturated with synthetic formation water, which was further reduced to initial water saturation and aged with crude oil. The plugs were flooded with varying preconditioning slugs combined with tested polymeric formulations.\u0000 This study provides an improved depiction of the interdependency of the key parameters and their associated response on displacement efficiency, which allows for a better understanding of SAP performance. The task concludes with an optimization study of the polymer selection criteria from development to design protocol.\u0000 In summary, a novel in-house SAP tailor made to fit the unique characteristics of candidate reservoirs was developed and tested for comparison with regular HPAM. This increased displacement efficiency (D.E), via simultaneous in-situ wettability alternation and sweep efficiency improvement, while minimizing the water and EOR flui","PeriodicalId":182237,"journal":{"name":"Day 3 Wed, October 23, 2019","volume":"6 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122529569","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Macroscopic Scale Interactions of Smartwater with Alkaline Chemicals for Enhanced Oil Recovery in Carbonates","authors":"Muhannad Alabdullateef, S. Ayirala, Salah Al-Saleh, A. Yousef","doi":"10.2118/198561-ms","DOIUrl":"https://doi.org/10.2118/198561-ms","url":null,"abstract":"\u0000 SmartWater flooding through tuning of injection water salinity and ionic composition is recently gaining good attention for enhanced oil recovery (EOR) in carbonates. The development of new hybrid recovery methods by capitalizing on the synergy with SmartWater can provide one potential optimization route for achieving more economic and effective EOR applications in the field.\u0000 In this experimental investigation, we evaluated the synergy of alkali with SmartWater through interfacial tension and contact angle measurements. These measurements were performed at reservoir conditions (2,500 psi and 70°C) using the crude oil and rock substrates from a carbonate reservoir. The high pH common alkali (NaOH) was used at dilute concentrations of 0.1 wt% in two different SmartWater recipes at a fixed low salinity (5,760 ppm TDS). The SmartWater recipes chosen include; 10-times reduced salinity seawater and low salinity water enriched with sulfates and without the divalent cations together with the seawater as baseline.\u0000 The contact angle results with high salinity seawater showed the strongly oil-wet behavior (140°) for a carbonate surface, which was favorably altered toward an intermediate-wet state (90°) with SmartWater recipes. The addition of alkali to 10-times reduced salinity seawater increased the contact angle to 152° due to alkali precipitate (formed by the reaction with divalent cations) preventing the interaction of key ions in the SmartWater with carbonate rock surface. A significant shift in the wettability toward a water - wet state (70°) was obtained by the addition of alkali to the SmartWater-enriched with sulfates to confirm the major role of pH on wettability alteration. In addition a reduction in the interfacial tension from 16.6 mN/m to about 7.2 mN/m was achieved by the addition of alkali to the SmartWater-enriched with sulfates in comparison to seawater, as a result of favorable alkali interactions with carboxylic acid groups present in the crude oil. The compounding of these beneficial wettability alteration and interfacial tension reduction effects observed with alkaline chemicals would further reduce capillary forces to mobilize relatively higher amounts of waterflood residual oil in carbonates.\u0000 This study is of practical significance as it successfully demonstrates the positive impact of combining SmartWater with alkaline chemicals for both wettability alteration and IFT reduction in carbonates at reservoir conditions. It also opens up a new avenue to exploit the use of synergistic alkaline based hybrid recovery processes for efficient and economical EOR applications in carbonate reservoirs.","PeriodicalId":182237,"journal":{"name":"Day 3 Wed, October 23, 2019","volume":"266 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133281862","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Enhanced Oil Recovery for Carbonate Oil Reservoir by Using Nano-Surfactant:Part II","authors":"Ali K. Alhuraishawy, R. S. Hamied, Hajir A. Hammood, W. Al-Bazzaz","doi":"10.2118/198666-ms","DOIUrl":"https://doi.org/10.2118/198666-ms","url":null,"abstract":"\u0000 Excellent attempts have been made worldwide to improve oil recovery. Nano technology features in EOR have been the focus of attention over the past century. The introduction of nanotechnology began in the late 1980s and was created to synthesize fresh nano-materials by rearranging atoms and molecules. Based on the small partition size of NPs (1-100) nm, the optical, thermal, chemical and structural properties of the nanomaterial differ completely from those shown by either its atoms or bulk materials. It is also clear that surfactants contribute to the stability of nanoparticles and emulsions with the aim of reducing IFT and changing rock wettability to water-wet.\u0000 The main objective of this study is to investigate the effects of nano particles and surfactant on improving oil recovery in carbonate reservoirs. Two key parameters were examined: silica nano particles and silica nano particles with Sodium Dodecyl sulfate (SDS) as an anionic surfactant. Finally, flooding test showed that using 0.03wt% SiO2 with 0.158 wt% SDS can improve oil recovery by 15.1% and minimize residual oil saturation to 25.6%. X-ray powder diffraction (XRD) and field emission scanning electron microscope (FESEM) were also done for thin core samples and the results have been discussed.","PeriodicalId":182237,"journal":{"name":"Day 3 Wed, October 23, 2019","volume":"48 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123108568","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Comprehensive 3 Dimensional Seismic Data Analysis to Comprehend Faults Distribution, Characteristics & their Significance in Controlling Hydrocarbon Accumulations in Brittle Carbonate Reservoirs: A Case Study in United Arab Emirates","authors":"A. Grover, T. A. Shabibi, A. L. E. Gazar, A. I. Latief, M. A. A. Amoudi","doi":"10.2118/198589-ms","DOIUrl":"https://doi.org/10.2118/198589-ms","url":null,"abstract":"\u0000 Structural architecture of fault zones, their distribution across the field and impact on migration pathways & reservoir permeability play an important part in field development. Inspiration for this study was limited understanding of role that faults play in brittle carbonate reservoirs. Extensive fault interpretation study was planned for quantification of orientations, segmentation, offset magnitudes and fault zones spacing to define their implications on fluid flow in terms of sealing capabilities within reservoirs. A systematic structural interpretation approach was established by exhausting the combination of regional tectonic history, 3D seismic interpretation techniques, advanced 3D visualization, BHIs, drilling data, production data, pressure data and MDT data. This resulted in better and more thorough definition of structures and hydrocarbon distribution in reservoirs.\u0000 Structural history of the field was analyzed to tie fault related observations with known tectonic events affecting reservoirs. A simple structural restoration with available data indicated that structures & fault zones probably resulted from regional WNW-ESE compression during late Cretaceous period. 3D seismic interpretation techniques & 3D visualization were exploited to interpret faulted zones present in the field. Geometrical attributes were extracted from conditioned seismic data to enhance discontinuities & edges. Interpreted faults were later tied with wells crossing faulted zones using BHIs & drilling data.\u0000 Thorough analysis reveals that major faults are actually assemblage of numerous segments. Furthermore, lateral and vertical displacement gradients are observed near tip lines of the fault planes. Relay-ramp behavior between fault segments are variable, mainly dependent on their orientation relative to prevailing maximum horizontal stress direction. Accordingly, positive (popups) and negative (sinkhole) structures can be found along the major faults. Two major faults having larger throws, as compared to other faults, divided the field into three parts, namely, northern, central & southern. Fault transmissibility varies as function of slip magnitude, diagenesis history leading to minerals filling, and their orientations relative to current maximum horizontal stress direction. Field dynamic data unveils that magnitude of slip is one of the most significant factors in explaining sealing capabilities of faults in reservoirs. Numerous wells have been drilled in central & southern parts of field with continuous production from wells in central part since 2005. Pressure records have shown no pressure change in southern part till date. Additionally, MDT results showed different FWLs and GOCs in both parts of field which also point to complete isolation.\u0000 Northern part of field is yet to be appraised. Possibility of faults, with significant throw separating the northern from the central part of the field, acting as a seal may not be ruled out. An appraisal well with","PeriodicalId":182237,"journal":{"name":"Day 3 Wed, October 23, 2019","volume":"287 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123451957","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Key Technologies and Practice of Ultra-HTHP Drilling in South China Sea","authors":"Dongsheng Xu, Jin Yang, Ying Zhao, Yi Huang, M. Luo, Yuan Chen, Lei Li, Yupeng Yang, Jie Wang, Minghe Zhang","doi":"10.2118/198549-ms","DOIUrl":"https://doi.org/10.2118/198549-ms","url":null,"abstract":"\u0000 Ultra-HTHP reservoirs are Contained in the deep strata of Yingqiong Basin in the South China Sea. The formation pressure coefficient is about 2.30, and the reservoir temperature is about 230℃. So the reservoir has the characteristics of low pressure bearing capacity and high collapse pressure, it poses great challenges to drilling operations.\u0000 Aiming at the difficulties of Ultra-HTHP wells, we carried out a series of studies. Firstly, We have done 2170 sets of experiments on rock properties to study drillability and viscoplasticity of rocks, the test conditions is 200℃ with confining pressures of 20 Mpa, 35 Mpa and 50 Mpa. Secondly, focusing on the problems of large surface casing and high risk of anti-collision in HTHP cluster wells, We improved drilling efficiency by pre-inclination drilling and anti-collision drilling. Finally, to protect reservoirs and reduce pollution, we invented a dual-effect drilling and completion fluid system with megatherm resistance.\u0000 After decades of research and public relations, we had completed a series of successful exploration and practice. Based on the law of viscoplastic change of rock under HTHP and rock breaking mechanism, we innovatively expounded a composite impactor acceleration tool with rotating and axial high frequency impact force characteristics. According to the principle of jet pump, a new type of speed-increasing jet-suction bit with bottom jet and reverse jet-suction dual-fluid channel had been creatively invented, it can increase the ROP of Ultra-HTHP wellbore by 162%. Ultra-HTHP cluster well surface drilling, pre-inclination, anti-collision one-trip high-efficiency drilling technology realizes the cluster well large-scale borehole drilling, pre-inclination, anti-collision three-in-one operation mode, it reduced the risk of anti-collision while improving the operation time, the single well construction period saved 2.5 days, and the average drilling cost saved 600 thousand RMB per day.Compared with conventional solid-phase drilling and completion fluids, the dual-effect drilling and completion fluids have high temperature, high density and low solid content decrease by 20%, mud cake thickness decreases by 60%, and permeability recovery value increases from 70% to more than 90%. Compared with the single well cost of cesium formate system in the world, single well saves 48 million RMB.\u0000 Ultra-HTHP wells had been successfully drilled 16 wells in the South China Sea, and the success rate is 100%. The average drilling cycle reduced from 175 days to 52 days, it is of great reference value for Ultra-HTHP drilling. It can be recommended to make Ultra-HTHP offshore areas such as the North Sea of Britain and the Gulf of Mexico of the United States.","PeriodicalId":182237,"journal":{"name":"Day 3 Wed, October 23, 2019","volume":"95 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126145088","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Digital Rock Technology Accelerates Carbonate Rock Laboratory Analysis","authors":"D. Klemin, A. Serebryanskaya, O. Savelev, S. Melnikov","doi":"10.2118/198610-ms","DOIUrl":"https://doi.org/10.2118/198610-ms","url":null,"abstract":"\u0000 This paper describe an application of combined experimental and digital technology workflow for field appraisal. It includes the description of heterogeneous low permeability X oil field located in the southeastern part of the Kurdistan Region of Iraq and its field development planning (FDP) challenges.\u0000 An integrated laboratory study of low permeability carbonate reservoir rocks (dolomitic limestones) included a digital rock (DR) workflow that accelerated the time to complete core analysis program while bringing vital information about the pore-scale flow dynamics. The DR workflow combined high-resolution digital rock imaging, digital fluid models of reservoir brine and live oil samples, detailed wettability model for sample aging and boundary conditions in digital coreflood experiments. DR imaging spanned from micro-CT for meso- and micropores to high-resolution SEM imaging of submicrometer porosity. Direct HydroDynamic flow simulator was used to model multiphase flow in digital experiments by solving equations of the density functional hydrodynamics (DFH). These equations are conservation laws for the mixture of chemical components, momentum, and energy with constitutive relations involving Helmholtz free energy or the entropy functional.\u0000 Samples were prepared for DR analysis and their representativeness was verified by obtaining routine properties of original plugs, trims, and mini-plugs selected for high-resolution DR imaging. We established the routine core analysis (RCA) properties of samples using DR and compared them with experimental data. Porous plate digital experiments were performed to obtain air-brine capillary pressure curves on all samples, with DR data verification with laboratory data on selected samples. A set of steady-state (SS) relative permeability digital experiments were then performed with live fluids at reservoir conditions. DR models were first fully saturated with brine and then de-saturated to water saturation that matched reservoir water saturation estimated from well logs. The SS cycle was performed after extended aging to establish a mixed-wet condition. SS relative permeability curves were obtained for all studied samples. DR modeling enabled looking at the dynamic changes of phase saturation in pores and significantly accelerated the laboratory program by performing porous plate tests 100-500 times faster and SS tests 20-50 times faster than conventional analysis using live fluids at pressure and temperature conditions surpassing operating ranges of laboratory equipment.\u0000 The comprehensive combined study (both laboratory tests and DR analysis) results determined the reservoir flow properties within the entire permeability range. It allowed to reduce uncertainties in predicting production levels, improved the forecast quality of the hydrodynamic model and reduced the difference between the minimum and maximum estimates of geological and recoverable reserves.","PeriodicalId":182237,"journal":{"name":"Day 3 Wed, October 23, 2019","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129928762","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Prediction of Water Saturation for Tight Sandstone Reservoirs by Using Array Dielectric Logging ADL","authors":"Hao-peng Guo, Zhang Haitao, Gao-ren Li, Xuecheng Yan, Wenjing Zhang, Yanmei Wang, Liang Xiao, Die Liu","doi":"10.2118/198653-ms","DOIUrl":"https://doi.org/10.2118/198653-ms","url":null,"abstract":"\u0000 Conventional hydrocarbon saturation estimation methods based on porosity and resistivity curves cannot be well used in our target formations due to the difficulty of the determination of necessary input parameters. The formation water resistivity was heavily affected by the various salinity. The water salinity was considered to have little effect to the delectric constant, especially for the delectric constants measured with frequency higher than 200 MHz. In this study, we proposed a new model to predict water saturation from the array delectric logging (ADL) data in the Chang 8 Formation of Penyang region, west Ordos Basin, west China. This model was similar with the classic Archie's equation in form, whereas the involved parameters were much easily to be determined. Based on the lab delectric constant measurements of 6 typical core samples, we determined the input parameters in this new model. Meanwhile, considering the effect of pore structure to delectric measurements, a model of calculating various mε from porosity was established. By using the proposed model, we processed several wells with which the ADL data was acquired, the consecutive water saturation curves were calculated. Comparisons of predicted water saturation with irreducible water saturation, core derived results and the drill stem test (DST) data illustrate that this model was reliable. The advantage of this model was that it can be used to precisely calculate water saturation in any formations with various formation water salinity, whereas the conventional methods lost their role.","PeriodicalId":182237,"journal":{"name":"Day 3 Wed, October 23, 2019","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130462392","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}