Day 3 Thu, March 28, 2019最新文献

{"title":"Study on Failure Mechanism of Cement Sheath Sealing of Shale Gas Well Under Alternating Loading and the Controlling Method","authors":"Shiming Zhou, Rengguang Liu, Q. Tao, Peiqing Lu, Xiaojiang Li","doi":"10.2523/IPTC-19481-MS","DOIUrl":"https://doi.org/10.2523/IPTC-19481-MS","url":null,"abstract":"\u0000 The continuously annulus pressure phenomenon is prominent in shale gas wells in China, which brings great challenges to safe and efficient development of shale gas. The main reason for the phenomenon is the sealing failure of cement sheath and one of important factors causing sealing failure of cement sheath is the alternating loading induced by massive hydraulic fracturing and wellbore temperature variation. Therefore, it is urgent to study the sealling failure mechanism under alternating stress, establish judging criteria for sealling failure and propose sealing controlling method. Triaxial stress instrument was used to test the mechanical properties of cement for cyclic loads under 5 different stress levels, based on these the residual strain model was obtained by fitting. The sealing evaluation device of full size cement sheath was developed to test the sealling of cement sheath under alternating dynamic loadding and the failure rule of cement sheath sealing was formed. The results showed that there was residual strain in cement after unloading and the accumulated residual strain increased with the increasing of cycle loading times. The model of residual strain was formed by fitting based on the large number of test results. Sealing failure occurred in the cement sheath after repeatedly alternating stress, which occurred in the unloading stage. Plastic deformation occurred in cement sheath under high loading, and residual strain was formed after unloading because the plastic deformation could not recover completely. Therefore, the deformation on the cement sheath interfaces was incompatible. The residual strain increased with the increase times of alternating stress same as that of the cement under cycle loading. The sealing failed when the accumulated residual strain exceeded the ultimate interface strain of the cement sheath interface and the cementation failure occurred. The judging criteria for sealing failure of cement sheath was proposed based on the fitted residual strain model. By reducing elastic modulus and maintaining the high strength of cement, the residual strain can be reduced under alternating stress. The sealing evaluation result showed that the sealing was enhanced of high-strength elastic cement sheath. So the sealing controlling method for cement sheath seal was formed.\u0000 Shale gas reservoirs belong to low-porosity and low-permeability gas reservoirs. Horizontal drilling and staged fracturing technologies are commonly used to achieve cost-effective development of such reservoirs (Fisher et al., 2004; Mayerhofer et al., 2010; Lin and Ma, 2015; Zhou et al., 2016). Although these wells had good cementing quality and no annulus pressure phenomenon occurred after cementing, sustained annulus pressure appeared after fracturing. The annulus pressure affects shale gas exploitation and brings about the problem of safety and environmental protection. Therefore, it is very necessary to study the sealing integrity of cement sheath un","PeriodicalId":11267,"journal":{"name":"Day 3 Thu, March 28, 2019","volume":"97 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91127889","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":"Integrated Real-Time Pressure Monitoring Enabled the Success of Drilling a HTHP Offshore Well: A Casing Study in Ledong Area of Yinggehai Basin, South China Sea","authors":"Yongde Gao, Ming Chen, Chao Du, Shiyue Wang, Dianqiang Sun, Peng Liu, Yanyan Chen","doi":"10.2523/IPTC-19313-MS","DOIUrl":"https://doi.org/10.2523/IPTC-19313-MS","url":null,"abstract":"\u0000 Drilling in Ledong field at Yinggehai basin of South China Sea faces challenges of high-temperature and high-pressure (HTHP). The high pore pressure and low fracture gradient results in a narrow mud weight window, especially when drilling close to overpressured reservoir. Well LD10-C was the first exploration well targeting at reservoirs in Meishan formation. Well LD10-A and LD10-B were offset wells in a distance of 15-20km drilled for reservoirs in Huangliu formation, which is above Meishan formation. During drilling, both wells encountered severe gas kick, mud loss and did not reach target.\u0000 In order to drill and complete well LD10-C safely, a real-time pressure monitoring solution was introduced with integration technique of logging while drilling (LWD) and look-ahead vertical seismic profile (VSP). It helped to monitor pore pressure and fracture gradient while drilling and predicted top of the overpressured reservoir. This enabled to keep the mud weight and equivalent circulation density (ECD) within a safe margin to avoid kick and mud loss, helped to set casing as close as possible to the top of reservoir. The reservoir section was drilled with a manageable mud weight window.\u0000 The main achievements of this task were: 1) accurately monitor and predicted pore pressure coefficient at reservoir. The predicted pore pressure coefficient was 2.25 SG versus 2.24 SG from actual measurement. 2) accurate prediction of reservoirs top. The predicted top depth of Sand C was 2m error with accuracy of 0.05%. The top depth of Sand D was 10m error with accuracy of 0.2%. 3) 12.25in section and 8.375in section was successfully drilled deeper with pressure monitoring. The 9 5/8in casing was set 491m deeper and 7in line was set 80m deeper than plan. As a result, well LD10-C was drilled and competed without any drilling complexities.\u0000 This was first application of LWD and VSP together for pressure monitoring while drilling in Yinggehai basin. The successful completion of well LD10-C confirmed that this integrated solution was an efficient technique to predict and reduce drilling risks, optimize mud weight and casing diagram, improve operational safety and save cost in HTHP offshore drilling.","PeriodicalId":11267,"journal":{"name":"Day 3 Thu, March 28, 2019","volume":"199 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77393450","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":"Improved Estimation and Forecast Through Model Error Estimation – Norne Field Example","authors":"Minjie Lu, Yan Chen","doi":"10.2523/IPTC-19142-MS","DOIUrl":"https://doi.org/10.2523/IPTC-19142-MS","url":null,"abstract":"\u0000 The ensemble based methods (especially various forms of iterative ensemble smoothers) have been proven to be effective in calibrating multiple reservoir models, so that they are consistent with historical production data. However, due to the complex nature of hydrocarbon reservoirs, the model calibration is never perfect, it is always a simplified version of reality with coarse representation and unmodeled physical processes. This flaw in the model that causes mismatch between actual observations and simulated data when ‘perfect’ model parameters are used as model input is known as ‘model error’. Assimilation of data without accounting for this model error can result in incorrect adjustment to model parameters, underestimation of prediction uncertainties and bias in forecasts.\u0000 In this paper, we investigate the benefit of recognising and accounting for model error when an iterative ensemble smoother is used to assimilate production data. The correlated ‘total error’ (combination of model error and observation error) are estimated from the data residual after a standard history matching using Levenberg-Marquardt form of iterative ensemble smoother (LM-EnRML). This total error is then used in further data assimilations to improve the model prediction and uncertain quantification from the final updated model ensemble. We first illustrate the method using a synthetic 2D five spot case, where some model errors are deliberately introduced, and the results are closely examined against the known ‘true’ model. Then the Norne field case is used to further evaluate the method.\u0000 The Norne model has previously been history matched using the LM-EnRML (Chen and Oliver, 2014), where cell-by-cell properties (permeability, porosity, net-to-gross, vertical transmissibility) and parameters related to fault transmissibility, depths of water-oil contacts and relative permeability function are adjusted to honour historical data. In this previous study, the authors highlighted the importance of including large amounts of model parameters, proper use of localization, and adjustment of data noise to account for modelling error. In the current study, we further improve the aspect regarding the quantification of model error. The results showed promising benefit of a systematic procedure of model diagnostics, model improvement and model error quantification during data assimilations.","PeriodicalId":11267,"journal":{"name":"Day 3 Thu, March 28, 2019","volume":"162 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76758323","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":"Determining Viscoelastic Models from Seismic Attenuation Measurements","authors":"Xu Liu, S. Greenhalgh","doi":"10.2523/IPTC-19073-MS","DOIUrl":"https://doi.org/10.2523/IPTC-19073-MS","url":null,"abstract":"\u0000 We have developed two simple deterministic methods to extract the parameters of viscoelastic models from seismic data. One is for the Zener model using phase velocity dispersion observations and the other is for the single fractional Zener model (Cole-Cole model) using attenuation versus frequency observations. The observations here represent either the arbitrary frequency-dependent dispersion behaviour from actual measurements or from some physical dissipation mechanism(s). In this contribution, it is also proved that similar to Zener model, the attenuation factor curve for the Cole-Cole model, on a logarithmic frequency-axis, symmetric about the frequency corresponding to the peak attenuation value, the peak frequency itself is equals to the inverse square root of the product of the two (stress and strain) relaxation times.\u0000 The Cole-Cole model has a broad dispersion response over an appreciable frequency range, but is not very suitable for replicating complicated seismic attenuation dispersion curves which exhibit multiple peaks. In this case, we use the General Zener (GZ) model comprising multiple Zener elements and the General Fractional Zener (GFZ) model comprising multiple Cole-Cole elements to approximate the attenuation observations. Their parameters, including relaxation times and fractional derivative orders, are determined using a simulated annealing inversion method. Instead of searching for the relaxation times directly, we search for the Zener peak attenuation points (attenuation value and corresponding frequency, each of which corresponds to a pair of relaxation times. There are distinct advantages of such an approach.","PeriodicalId":11267,"journal":{"name":"Day 3 Thu, March 28, 2019","volume":"215 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89649367","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":"A Geoengineering Long March to Success: An Overview of the Development of Keshen Gas Field in Kucha Foreland Basin","authors":"T. Jiang, Chenggang Xian, Xiangtong Yang, Yongjie Huang, Yang Zhang, Yuanwei Pan","doi":"10.2523/IPTC-19483-MS","DOIUrl":"https://doi.org/10.2523/IPTC-19483-MS","url":null,"abstract":"\u0000 Significant challenges meeting together make Keshen gas field in Kucha foreland basin become unique from geosciences, engineering and economics points of view. These challenges generally link to harsh geography, super deep (>6500m TVD), thick conglomerates (up to 3000m), heterogeneous salt-gypsum laminations (up to 2000m), complex thrust-nappe structure, HTHP, and ultra-tight (matrix permeability < 0.1 md). This paper gives a comprehensive review how the geoengineering Long March assists to successfully develop this field.\u0000 A geoengineering team was established to persistently attack on this world-class championship with high-level planning since 2012. Specific research and development of engineering technologies and solutions for data acquisition, drilling, completion, stimulation, testing and production and studies were taking place in parallel. To ensure seamless integration from geosciences and engineering to operation, a five-year geoengineering study was proactively and progressively executed which includes four major steps with respective objectives including 1) understanding fluid distribution and producibility, 2) well production breakthrough and enhancement, 3) optimization of well stimulation and economics, and 4) optimization of field management including surprising sanding problem.\u0000 It was recognized three elements and their interactions are critical for production enhancement which are natural fracture (NF) characteristics, production controlling mechanism, and stimulation optimization under super deep, HPHT and extremely high stress conditions. The bottleneck for study was poor seismic quality due to super depth, pre-salt, and complex thrust-nappe structures. Hence the team established comprehensive methodologies with iterative improvements to overcome this bottleneck. Using regional structural geology, outcrops, cores, images and logs as inputs, structure restoration and geomechanics simulators were combined to perform structure restoration, paleo-stresses, and in-situ stresses and eventually 3D NF prediction. To understand production mechanism, analysis of geological and geomechanical factors, NF and stress relationships, single parameter and multiple variables, and transient and production performance were integrated. Big core studies were conducted to understand fracability, NF and hydraulic fracture (HF) interactions, and selections of HF fluids. Based upon, a stimulation optimization approach was implemented which included engineered completion designs, HF modeling and parametric studies, post-frac analysis and optimization, and time effects through high-resolution coupled geomechanics and reservoir simulation. All efforts with evolving knowledge were eventually developed as an interactive expert system to guide systematic stimulation optimization, sanding management and development optimization.\u0000 With increasing understanding of reservoir, and implementing innovative solutions, it was enabled to drill wells at optimal loca","PeriodicalId":11267,"journal":{"name":"Day 3 Thu, March 28, 2019","volume":"195 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86991234","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":"The Successful Selection, Optimization and Implementation of Adjust While Drilling AWD Flowchart in Offshore Oil Field of Bohai Bay, China","authors":"Yifan He, Yong Hu, Hongfu Shi, Zhou Junliang, Xiao Shu","doi":"10.2523/IPTC-19441-MS","DOIUrl":"https://doi.org/10.2523/IPTC-19441-MS","url":null,"abstract":"\u0000 BZ field is located at Bohai Bay of China, it is featured with multiple complex fluvial reservoirs with small lateral extension (100-300m wide) and thin accumulation (6-12m). Many channels are isolated and poorly connected across the field. As a result of the fluvial narrowness, low reserve abundance and limited natural energy, the development of this field was tied back into the neighboring field facilities and was categorized as the marginal value field with low ROR (rate of return). This paper presents a successful implementation of the flowchart of \"adjust while drilling\" to tap these kinds of reservoirs during the E&P circles.\u0000 In the ODP design phase, 13 well slots were reserved for the future use. And the overall geological characteristics is predicted to be much complex.\u0000 In order to mitigate risks, identify potential opportunities and improve the benefit of plan, a work flow integrating seismic, geology, logging and productivity forecast, with exploration concepts was designed during development phase to optimize drilling schemes.\u0000 The process is divided into 5 steps: 1. Locate and characterize key sands by combined analysis of logging and seismic data. 2. Recognize hydrocarbon migration pattern, identify potential oil-bearing sands, and estimate OOIP; 3. Design well patterns and forecast productivity based on the reservoir characteristics and OOIP. 4. Optimize drilling sequence and well trajectory; evaluate reservoir potential and risks based on data from drilled wells, and then optimize future well locations. 5. Apply logging while during drilling (LWD) and Periscope to reach optimal landing point and ensure high NTG.\u0000 Modifications to the ODP mainly include: 1. Staggered line well pattern was adopted to develop single story channel. 2. A large number of horizontal wells were adopted. 3. Understanding on the relationship between production wells and injection wells were improved by placing the deviated injection wells at the multi-stored channel stacking. And the well spacing was determined based on the updated reservoir properties to warrant waterflood sweeping conformance and efficiency. 4. Newly proved potentials were targeted through remaining reserved slots.\u0000 Through this process, OOIP has increased by 108%, production well counting has risen from 19 to 32, locations of 9 wells reserved during ODP phase have been successfully optimized and redirected; independent P-I pairs have been positioned for each single story channel with the P-I ratio over 90% and good response between those pairs. Average productivity has reached 1.5 times of the designed level.\u0000 The overall successful development of BZ field has proved the effectiveness of the flowchart, which is designed for the risk mitigation, potential tapping, slot utilization and financial performance enhancement. Therefore, it provides an insightful guidance for the future similar reservoirs development program design.","PeriodicalId":11267,"journal":{"name":"Day 3 Thu, March 28, 2019","volume":"16 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87506621","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":"Integration of Latest Laboratory, Software and Retarded Acid Technologies to Increase Efficiency of Acid Treatments in Carbonates: Case Studies from Central Asia","authors":"D. Abdrazakov, M. Ziauddin, D. Vernigora, A. Beletskaya, I. Yakimchuk, O. Olennikova, D. Usoltsev, Max Nikolaev, M. Panga, A. Burlibayev","doi":"10.2523/IPTC-19546-MS","DOIUrl":"https://doi.org/10.2523/IPTC-19546-MS","url":null,"abstract":"\u0000 Acidizing treatments in carbonates often result in significant skin decrease due to high reactivity of the formation with acids. Noticeable production increase or inability to run analysis tools after the treatment may lead to the conclusion that the matrix acidizing job was performed efficiently, when, in fact, the job was not optimized in terms of fluid volumes, acid types, wellbore coverage, and pumping rates. As a result, the final skin is not as low as it could be, and, most importantly, medium - and long-term post-acidizing production decline is faster than it could be with an optimized treatment.\u0000 To overcome these concerns, an integrated approach to acidizing treatments was implemented for different oil fields in Kazakhstan. The integrated approach consists of comprehensive laboratory testing, which includes core flow tests with subsequent 3D computer tomography scanning. The tests help to determine wormholing regimes and channel geometry while providing calibration points for acid-rock interaction curves. These coefficients are used in the acidizing modeling software, which enables optimization of fluid volumes, pumping rates, and diversion strategy. The approach suggests the use of a single-phase retarded acid system is the most effective method of keeping the treatment in the dominant wormhole regime, especially at elevated temperature. The integrated approach loop is closed by the analysis of the distributed temperature sensor data to calibrate the efficiency of diversion and reservoir injectivity profile.\u0000 The approach was introduced for different oil fields in Kazakhstan, with a variety of conditions: depths up to 5000 m and temperatures up to 145°C. The approach helped to optimize acid volumes by as much as 44% to achieve an optimum skin. In the mid-term perspective, this approach helped to reduce the production decline rate by at least 20%, and ongoing post-treatment analysis is even more promising.","PeriodicalId":11267,"journal":{"name":"Day 3 Thu, March 28, 2019","volume":"27 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88156231","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":"Use of N115 Carbon Nano-Fluid for Solar Powered Steam Assisted Gravity Drainage for Extracting Bitumen","authors":"Lijo P. Lalu, R. Lal","doi":"10.2523/IPTC-19088-MS","DOIUrl":"https://doi.org/10.2523/IPTC-19088-MS","url":null,"abstract":"\u0000 Showing concern for the high emission of green house gases, the governments all over the world are coming up with more stringent rules to check the emission level. Steam Assisted Gravity Drainage is a highly energy intensive process where huge amount of steam is generated by heating natural gas or coal thereby generating a very large share of green house gases. Therefore, solar energy seems to be lucrative in the following ways: world areas with abundant solar irradiation level can be tapped to reduce the fossil fuel consumption, minimizing the cost spent on fossil fuel and the emissions level at the same time. Concentrated Solar Power (CSP) looks a very promising technique but it comes with its own limitations mainly due to the requirement for huge area for setting up the solar collectors. Water Soluble Carbon-N115 is a sub-micrometer particle that has size less than the wavelength of light. Due to this reason, instead of scattering light, it absorbs light. The nano-particle gets enveloped in a thin layer of steam when put in a water bath. The vapour is released after reaching liquid-air interface and the nano-particles revert back to the solution to repeat the vaporization process and they exchange heat with the fluid, slightly raising the fluid temperature resulting in boiling of the fluid volume as a parallel effect. The paper discusses a model incorporating this nano-particle for the reduction of solar field footprint by more than a quarter and thereby reducing the cost and operational area. The paper also suggests the places across the globe where the proposed method can be deployed for generating steam and ultimately injecting it for producing oil above the surface from a tar-sand reservoir.","PeriodicalId":11267,"journal":{"name":"Day 3 Thu, March 28, 2019","volume":"30 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90238269","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":"Less Damaging Drilling Fluids: Development and Lab Testing","authors":"Sara Alkhalaf, Mohammed B. Al-Awami, V. Wagle, A. Al-Yami","doi":"10.2523/IPTC-19205-MS","DOIUrl":"https://doi.org/10.2523/IPTC-19205-MS","url":null,"abstract":"\u0000 The properties of the selected drilling fluid must be carefully planned to have minimal effects on the near-wellbore pore spaces. Proper mixing, monitoring, and maintenance of the drilling fluid throughout the drilling operations are as critical as the careful planning. Solids control equipment should be operated to remove the cuttings and maintain the density and rheological properties consistent.\u0000 The characteristics of an effective reservoir fluid system include stability at high pressures and temperatures, proper and stable density, good filtration control, ability to transport cuttings, and minimal damage to formation pore spaces, Davidson et al. 1997. Selection of the most suitable drilling fluid additives takes into consideration numerous factors such as downhole conditions (pressure and temperature), formation type and petro physical properties, and the objective of the drilling operation.\u0000 The experimental work in this paper involved rheological properties, thermal stability, API and HT/HP filtration and acid filter cake removal efficiency.\u0000 Tangentional flooding showed that water based Mn3O4 drill-in fluid has the highest return permeability compared to the typical drill-in fluids (KCl/CaCO3/Barite and potassium drill-in fluids). Potassium formate drill-in fluid filtrate was not compatible with brine. This incompatibility explained its low return permeability in spite of its low solids content. Oil based drilling fluid was developed and tested with good acceptable results. Filter cake removal efficiency was showing more than 95%, indicating its removable formation damage.","PeriodicalId":11267,"journal":{"name":"Day 3 Thu, March 28, 2019","volume":"29 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79405254","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":"Advanced Meandering Fluvial Reservoir Characterisation for Static Model Improvement","authors":"H. Ismail, C. L. Lew, Muhd Rapi Mohamad Som, M. Kadir, M. Tajuddin","doi":"10.2523/IPTC-19352-MS","DOIUrl":"https://doi.org/10.2523/IPTC-19352-MS","url":null,"abstract":"\u0000 Modelling of meandering fluvial reservoirs with point bars and crevasse splays is very challenging. The conventional modelling approaches, especially for meandering fluvial reservoirs, are mainly controlled by wells, which have contributed to uncertainties in lateral variations between and away from well control. Integration of the improved sedimentology, geophysics and 3D reservoir geomodelling techniques of fluvial reservoir system are proposed in the study. In stratigraphic and structural framework building, the improved methodologies included 3D seismic geobody extraction, stratal slicing and high order architectural elements interpretation. 3D geobody extraction and stratal slicing technique enhanced interpreter ability to visualize fluvial features at specific time-equivalent stratigraphic surface. In lithofacies modelling, more refined high-order architectural elements were modelled using methodologies included 3D facies seismic probability, local varying azimuth and dip angle to capture lateral accretion of point bars inside the channels for better facies distributions following point bar architectures. In property modelling, porosity was populated using Gaussian Random Function Simulation constraint to lithofacies trend to control the distribution of porosity away from wells. This methodology resulted in the porosity distributions being well controlled following the lithofacies trend. The proposed workflows and methodologies enable geomodeller to produce a more geological realistic meandering fluvial reservoir model with internal lithofacies and property distribution honouring well data and input distribution.","PeriodicalId":11267,"journal":{"name":"Day 3 Thu, March 28, 2019","volume":"77 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84059896","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}