Day 1 Mon, September 30, 2019最新文献

{"title":"Cluster Flow Identification During Multi-Rate Testing Using a Wireline Tractor Conveyed Distributed Fiber Optic Sensing System With Engineered Fiber on a HPHT Horizontal Unconventional Gas Producer in the Liard Basin","authors":"C. Cerrahoglu, G. Naldrett, Adam Vigrass, R. Aghayev","doi":"10.2118/196120-ms","DOIUrl":"https://doi.org/10.2118/196120-ms","url":null,"abstract":"\u0000 This paper investigates the flow performance of a horizontal unconventional gas producer where cluster flow has been detected and quantified. The method employed is the first use of a wireline deployed engineered fiber optic Distributed Acoustic Sensing (DAS) system for the purpose of production monitoring. It further describes the technological advancement of the DAS system.\u0000 While distributed fiber optics sensors have been used in unconventional wells for over ten years, the focus has been on stimulation monitoring, where relatively large thermal and acoustic signatures are easily measured. There has been limited success on the use of the same systems for production monitoring in horizontal wells since the thermal and acoustic flow signatures are very small. The recent technological advancements achieved in the area of Distributed Acoustic Sensing, using engineered fibers with dramatic improvements in the signal-to noise ratio, now make it possible to sense low levels of inflow noise with DAS systems. This study presents two distinct ways of analysing DAS data to extract production information and demonstrates the analysis using real field data.\u0000 The well is an unconventional dry gas producer in the Liard Basin, Canada, which was completed in 18 stages, with 3 cluster per stage, a total of 54 clusters along a horizontal section of ~2000m. The top 11 stages were logged on tractor conveyed wireline with DAS and DTS data acquired over a 19-hour period. The acquisition covered an initial shut-in period, followed by a ramp up to a maximum test rate, and a final shut-in period. Data from the full acquisition period was analysed and is presented in the paper.\u0000 The data acquired at various points during the acquisition period was used to detect and quantify inflow. It was found that one of the clusters was active throughout the shut-in period and inactive during the maximum test rate. We were also able to identify more clusters being activated as the production rate increased. The increase in the number of active clusters was not proportional to the increase in the surface gas rate, with heel side clusters becoming active before the toe side clusters as the production rate was increased. The results of this survey yielded remarkable insights that informed the operator on the completion efficiency and the relationship between the total production rate and cluster activity.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"34 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-11-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125692044","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":"West Nile Delta Campaign Delivering Energy to Egypt","authors":"Sherine Khedr, Fady El-dabi, M. Nashaat, G. Mohiuldin, Alaa Galal, Teddy Slim, Andrea Hughes, Lyndsay Morris, D. Ramsay, Wael El-wakeel, Hussein Mubarak, Jeffrey B. Smith, R. Munger","doi":"10.2118/195809-ms","DOIUrl":"https://doi.org/10.2118/195809-ms","url":null,"abstract":"\u0000 Giza Fayoum Completions was the second campaign of the West Nile Delta project. The campaign consisted of eight cased-hole gravel pack subsea wells. The Giza Fayoum campaign was sanctioned in August 2017 with an execution start date five months later. In this time, the well designs were finalized, downhole completion equipment manufactured, and the execution plan approved. A high rate water pack sand control technique was designed to deliver an estimated production rate of 120 MMscf/d / well. It was planned to deliver eight wells over a period of 5 months from Q1 2018 giving an average of two and a half weeks per well. Seven of the eight wells were cleaned up through a large bore completion landing string system. Each well was flowed to high rate temporary well test equipment installed on the DP semi-submersible rig to a gas rate of 65 MMscf/d, with PLT logs conducted.\u0000 This successful, fast-paced campaign is the result of applying lessons learned from the former campaign; Taurus Libra and identifying additional efficiencies that would improve performance. The design similarities between the two campaigns permitted the team to extend the learning curve and deliver superb performance on Giza Fayoum.\u0000 As for safety performance, the campaign was delivered without any lost time incident. A rigorous approach to continuous improvement resulted in reducing the completion time to 12 days per well (not including rig move, de-suspension and suspension activities). The optimized bean up procedures supported by PLT data made it possible to reduce greenhouse emissions by 20%. The sand control technique resulted in a significant reduction of total skins. Moreover, the team succeeded in delivering the wells safely, ahead of plan and under budget while adhering to BP's overarching strategy of delivering safe, compliant and reliable wells.\u0000 The efficiencies, safety culture and technology used during this campaign are now being set as the standard for future campaigns in Egypt and beyond.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"14 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121795887","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":"Case Studies: Optimizing BHA Performance by Leveraging Data and Advanced Modeling","authors":"M. Shahri, M. James, Alan Vasicek, R. Napoli, M. White, M. Behounek, J. D'Angelo, P. Ashok, E. Oort","doi":"10.2118/196020-ms","DOIUrl":"https://doi.org/10.2118/196020-ms","url":null,"abstract":"\u0000 Given the intensity of drilling operations in the North American unconventional reservoirs and the quality and amount of data gathered during a drilling operation, leveraging those data along with advanced modeling techniques for optimization purposes is becoming more feasible. In this study, historical data and advanced physical modeling are utilized to better understand and optimize the bottom-hole assembly (BHA) performance in drilling operations. A comprehensive data set is gathered for more than 300 BHA runs in the span of three years. This extensive data set enables thorough examination of the variation in the operational parameters and its effect on the drilling performance.\u0000 Different indices are used to determine and evaluate drilling performance, such as rate of penetration (ROP). Excessive tortuosity in a well can have many detrimental effects while drilling such as excessive and erratic torque and drag, poor hole cleaning (cuttings removal), low ROP, along with problematic casing and/or liner runs and associated cementing procedures. In this paper, a tortuosity index (TI) is used to quantify the drilled well quality and correlate it to ultimate drilling performance. In the next step, patterns are extracted and used along with physical modeling for optimizing drilling performance before the well is drilled.\u0000 The corresponding tortuosity index can be used as a proxy for the well path smoothness and may be used for quantifying parameters affecting drilling performance. According to historical drilling performance data, there appears to be a strong relationship between wellbore tortuosity and ROP. If drilling operating parameters (e.g., BHA configuration, directional company's performance, target formations, bit specification, mud types, etc.) can be related to the TI based on historical data, such parameters can be modified for optimizing the performance before the well is drilled.\u0000 By investigating the historical data, different trends have been extracted. In addition, different models can be built to predict drilling performance (e.g., TI) prior to drilling and according to new well design specifications. Based on data from more than 300 BHA runs and using advanced physical modeling, the most strongly correlated parameters to drilling performance have been determined and shown using different case studies. Such a historical database along with modeling techniques are used to predict well quality and drilling performance during the design phase. Using this method, well design specifications can then be optimized to enhance drilling performance and reduce the cost.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"48 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115535606","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":"Using Nanoparticles Coating to Enhance Proppant Functions to Achieve Sustainable Production","authors":"M. Tabatabaei, A. D. Taleghani, Yuzhe Cai, L. Santos, N. Alem","doi":"10.2118/196067-ms","DOIUrl":"https://doi.org/10.2118/196067-ms","url":null,"abstract":"\u0000 Proppant bed plays a critical role in enhancing oil and gas production in stimulated wells. In the last two decades, there have been consistent efforts to improve shape characteristics and mechanical strength properties to guarantee high permeability in the resultant propped fracture. However tuning wettability of proppants have not yet engineered considerably maybe because natural sand has been a typical raw material for proppant manufacturing. However, water wet proppants may not only limit production due to reduced hydrocarbon relative permeability but also facilitate fine migration through the proppant bed. Fine migration and increasing water saturation may deteriorate oil production over time. Intrinsic hydrophobicity of graphitic surfaces and their two-dimensional geometries made them a promising candidate for coating proppant to alter its wettability. In this paper, we present a methodology for treating proppant surfaces with graphite nanoplatelets. Standard laboratory tests following modified API RP61 have conducted to show the effectiveness of the proposed methodology.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"174 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116133845","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":"Case Study: Optimizing Eagle Ford Field Development Through a Fully Integrated Workflow","authors":"Adrián Morales, R. Holman, Drew Nugent, JingJing Wang, Zach Reece, C. Madubuike, Santiago Flores, T. Berndt, Vincent Nowaczewski, Stephanie Cook, Amanda Trumbo, Rachel Keng, Julieta Vallejo, Rex Richard","doi":"10.2118/195951-ms","DOIUrl":"https://doi.org/10.2118/195951-ms","url":null,"abstract":"\u0000 An integrated project can take many forms depending on available data. As simple as a horizontally isotropic model with estimated hydraulic fracture geometries used for simple approximations, to a large scale seismic to simulation workflow. Presented is a large-scale workflow designed to take into consideration a vast source of data.\u0000 In this study, the team investigates a development area in the Eagle Ford rich in data acquisition. We develop a robust workflow, taking into account field data acquisition (seismic, 4D seismic and chemical tracers), laboratory (geomechanical, geochemistry and PVT) measurements and correlations, petrophysical measurements (characterization, facies, electrical borehole image), real time field surveillance (microseismic, MTI, fracture hit prevention and mitigation program through pressure monitoring) and finally integrating all the components of a complex large scale project into a common simulation platform (seismic, geomodelling, hydraulic fracturing and reservoir simulation) which is used to run sensitivities.\u0000 The workflow developed and applied for this project can be scaled for projects of any size depending on the data available. After integrating data from various disciplines, the following primary drivers and reservoir understanding can be concluded. At a given oil price, optimum well spacing for a given completion strategy can be developed to maximize rate of return of the project. Many operators function in isolated teams with a genuine effort for collaboration, however genuine effort is not enough for a successful integrated modelling project, a dedicated multidisciplinary team is required.\u0000 We present what is to our knowledge, one of the most complete data sets used for an integrated modelling project to be presented to the public. The specific lessons from the project are applied to future Eagle Ford projects, while the overall workflow developed can be tailored and applied to any future field developments.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116843482","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":"Best Practices of Exploration: Integration of Seismic and Electrical Prospecting","authors":"V. Vorobev, I. Safarov, P. Mostovoy, L. Shakirzyanov, V. Fagereva","doi":"10.2118/196138-ms","DOIUrl":"https://doi.org/10.2118/196138-ms","url":null,"abstract":"\u0000 Eastern Siberia is characterized by the extremely complex geological structure. The main factors include multiple faults, trappean and salt tectonics, the complex structure of the upper part of the section (0–1200 m) and its high-velocity characteristic (5000–6000 m/s), the high degree of rock transformation by secondary processes, low formation temperatures (10–30°C), the mixed fluid composition (gas, oil and water), and low net thicknesses (5–7 m) of productive layers. The fields of the region are among the most complex ones in the world according to the BP Company's statistics. New seismic and geologic model based on complex analyses of core, well logs, well tests, seismic and electromagnetic data allowed the Gazpromneft-GEO company to drill a series of successful wells.\u0000 Gazpromneft-GEO, LLC.holds three oil and gas exploration and production licenses within the Ignyalinsky, Vakunaisky and Tympuchikansky (Chona field) subsurface blocks (Russia, Eastern Siberia, Irkutsk Region and Republic of Sakha (Yakutia)). The area of the blocks is 6,855 sq.km, 3,050 sq.km of which are covered by the 3D seismic and high-density electric prospecting (Fig. 1). 70 exploration wells were drilled. The geological oil reserves of the Chona field are about 500 Mt. Nonetheless, the level of study of the blocks is extremely irregular, despite such significant reserves. To transfer from the exploration stage to production the capital-intensive scope of exploration is required, which expands the exploration program in time and can influence the final economic profitability of the project. The optimization of drilling costs by minimization of drilling wells and the efficiency of their drilling is the key purpose of the project.\u0000 The work was carried out within the frames of scientific research and field works at the Gazpromneft-GEO, LLC. fields in Eastern Siberia. The high-density full-azimuth ground-based seismic using the UniQ technology was performed in Russia for the first time. The electric exploration with the near-field time-domain electromagnetic method was carried out along the same lines for the first time in Russia as well. This allowed to form the high-density cube of geoelectric properties. Model based on the wells (Facies model, Petrophysics model) and field geophysical data (3D seismic survey, 3D electric exploration, gravimetric survey, magnetic survey) complexation was made. The use of the approach allows to reduce the number of wells required for exploration of fields by 40%.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"46 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128368028","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":"Application of Inter-Fracture Injection and Production in a Cluster Well to Enhance Oil Recovery","authors":"Youwei He, Shiqing Cheng, Z. Chai, S. Patil, Ray Rui, Haiyang Yu","doi":"10.2118/196017-ms","DOIUrl":"https://doi.org/10.2118/196017-ms","url":null,"abstract":"\u0000 Applications of cluster wells and hydraulic fracturing enable commercial productivity from unconventional reservoirs. However, well productivity decrease rapidly for this type of reservoirs, and in many cases, it is difficult to maintain a productivity that is economical. Enhanced oil recovery (EOR) is therefore needed to improve well performance. Traditional fluid injection from other wells are not feasible due to the ultra-low permeability, and fluid Huff-n-Puff also fails to meet the expected recovery. This work investigates the feasibility of the inter-fracture injection and production (IFIP) approach to increase oil production of multiple multi-fractured horizontal wells (MFHW).\u0000 Three MFHWs are considered in a cluster well. Each MFHW includes injection fractures (IFs) and recovery fractures (RFs). The fractures with even and odd indexes are assigned to be IFs or RFs, respectively. The injection/production schedule falls into two categories: synchronous inter-fracture injection and production (s-IFIP) and asynchronous inter-fracture injection and production (a-IFIP). To analyze the well performance of multiple MFHWs using the IFIP method, this work performs numerical simulation based on the compartmental embedded discrete fracture model (cEDFM) and compares the production performance of three MFHWs using four different producing methods (i.e., primary depletion, CO2 Huff-n-Puff, s-IFIP, and a-IFIP). Although the number of producing fractures is reduced by about 50% for s-IFIP and a-IFIP, they achieve much higher oil rates than primary depletion and CO2 Huff-n-Puff. Sensitivity analysis is performed to investigate the impact of parameters on the IFIP. The fracture spacing between IFs and RFs, CO2 injection rates, and connectivity of fracture networks affect the oil production significantly, followed by length of RFs, well spacing among MFHWs and length of IFs. The suggested well completion scheme is presented for the a-IFIP and s-IFIP methods. This work demonstrates the ability of the IFIP method in enhancing oil production of multiple MFHWs in unconventional reservoirs.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121417031","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":"Visual Support for Heavy-Oil Emulsification and its Stability for Cold-Production using Chemical and Nano-Particles","authors":"Jungin Lee, Jingjing Huang, T. Babadagli","doi":"10.2118/196023-ms","DOIUrl":"https://doi.org/10.2118/196023-ms","url":null,"abstract":"\u0000 The performance of non-thermal, cold, heavy oil production methods, such as waterflooding or gas injection (foamy oil) applications, is predominantly limited. As an alternative, efficient chemical flooding has been recommended and tested around the world (mainly in Canada and China). Cost aside, the main issue with this application is the compatibility of the chemicals used in terms of rock type, salinity, temperature, and emulsion generation and stability. Low-cost materials with strong emulsion stability capability have been tested previously in our research group. As an ongoing part of our past studies on the extensive chemical flooding applications in enhanced heavy oil recovery, we visualize directional motion, patterns, and deformation of fingers observed in Hele-Shaw cells with different oil types (heavy oil of 13,850 cP at 21°C from western Canada, heavy mineral oil of 649.9 cP at 20°C.\u0000 Macroscopic and microscopic visualizations allow us to gain insights into important and fundamental physical flow mechanisms such as the Saffman-Taylor instabilities due to the viscosity ratio, and the Marangoni effect due to the surface tension gradient, wetting, dewetting, and superspreading behaviors. Hele-Shaw visualization studies in the past have mainly focused on weakening or eliminating the fingering instabilities. In this study, we attempt to categorize the observed finger types which appear during the displacement, identify the finger types responsible for heavy oil-in-water emulsification, and relate the visualization results to final enhanced heavy oil recovery. We observe both miscible and immiscible flow behavior and in the case of immiscible flow, and we investigate the impact of the capillary number on finger growth and ramification patterns by manipulating the flow rates.\u0000 There are a plethora of factors that may impact the visualization of heavy-oil emulsification including the fixed chemical properties, chemical compatibility, heterogeneous (or non-heterogeneous) chemical reaction, capillary number effect, mobility ratio, IFT gradient, chemical concentration, liquid-substrate wettability, pH of liquids, precipitation, and brine conditions. To investigate such impact, we investigated a large series of in-situ heavy oil-in-water emulsifications at various conditions using emulsifiers such as anionic surfactants, cationic surfactants, and NaOH. And for the stabilization of the emulsions formed with the emulsifiers, we tested nanofluids (silica, cellulose nanocrystal, zirconia, alumina) and polymer (Xanthan Gum and an anionic polyacrylamide-based polymer). The results displayed that there exist finger types which are responsible for stable Winsor type 4 heavy oil-in-water emulsification. By the method of controlling the infrastructure of emulsion droplets and correlating observed multiple finger interactions to the material designs, we enable the selection of both novel and cost-effective designs for heavy oil recovery as well as displace","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"34 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116179294","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":"Improving Sweep Efficiency by Zonal Isolation Using High Expansion Ratio Inflatable Plugs - A Case Study II","authors":"Manish Kumar, N. Varma, G. Dangwal, Manoj K Gupta, P. Srivastava, P. Shrivastava, Chintan R Maniar, Satish Nekkanti, A. Bohra, Krishana Chandak, A. Pandey, Ankesh Nagar, Vaibhav Gupta, Subhamoy Mukherjee","doi":"10.2118/195913-ms","DOIUrl":"https://doi.org/10.2118/195913-ms","url":null,"abstract":"\u0000 This abstract is submitted as an addendum to SPE-188853-MS, which deliberate about Improving Sweep Efficiency by Zonal Isolation Using High Expansion Ratio Inflatable Plugs. \"M\" field contains medium gravity viscous crude (10-20cp) in high permeability sands. Application of EOR technique is considered pivotal in sustaining the plateau production rate and maximizing the ultimate recovery from this field. \"M\" field is currently under polymer flooding with wells completed in a 5-spot pattern. The high viscosity crude in this field, with an unfavorable mobility-ratio with water, mandated the need to switch from water to polymer flooding. Even though good sweep improvement was observed in most of the patterns, a few pattern producers didn't respond to polymer flood as expected. They exhibited poor sweep efficiency which resulted in bypassed oil and early water/polymer breakthrough. The poor sweep efficiency adversely affects the project economics by reducing the Expected Ultimate Recovery (EUR) and increasing the opex associated with produced water handling.\u0000 Paper SPE-188853-MS outlined how the installation of \"high expansion ratio inflatable plugs\" in the pattern producers, improved sweep efficiency. This paper adds further case studies to it, carrying forward the success of these Plugs.\u0000 Moving onward the process of isolation based on detailed analysis of pattern flood producer wells which were shut-in, due to high water-cut and production handling constraints. Saturation log were carried out to locate the poorly swept sand zones. Also, since most of the wells are sub hydrostatic and exist on artificial lift. N2 assisted PLT were carried out to identify high water cut zones and accordingly zonal isolation of such high water cut zones were planned. Temporary isolation was required to accommodate plans for future ASP (Alkaline Surfactant Polymer) flooding. Both mechanical and chemical isolation methods were explored and accordingly well candidates were identified for each of the methods for isolation. Mechanical isolation methods are discussed in the paper (chemical isolation being discussed in a separate paper). Last paper gave insight about plug passing through a minimum ID of 2.3\" and set in a 7\" production casing. After this campaign, more candidates with plug setting section of 9-5/8\" Casing & 4-1/2\" Screens were selected. Plug setting with Coil Tubing & E-line were explored and executed.\u0000 The jobs were successfully conducted in around 30 producer wells. The isolation resulted in a 3-4-fold increase in the instantaneous oil production with around 40% drop in produced water cut. This demonstrated how the treatments improved the selective drainage of the poorly swept sands by allowing preferential movement of flood front in these sands.\u0000 To support selective treatment of injector wells for sweep bypassed oil sands, through tubing inflatable straddle packer acidization jobs are being planned to further increase the injection in poorly swept zones","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"18 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134009495","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":"Simulation of Fault Reactivation Using the HISS Model","authors":"Jenny Ryu, D. Espinoza, M. Balhoff, S. Tavassoli","doi":"10.2118/196153-ms","DOIUrl":"https://doi.org/10.2118/196153-ms","url":null,"abstract":"\u0000 Long-term integrity and practical storage of CO2 is contingent upon its seal performance and the dynamic sealing capacity of faults for the CO2 storage site. Faults are prone to reactivation with reservoir pressurization caused by CO2 injection. The goal of this study is to create and verify a reservoir elasto-plastic model capable of capturing short-term evolution of fault reactivation and the resulting change of permeability. This model is then used to explore the effects of coupling geomechanics with reservoir fluid flow on the reactivation of faults.\u0000 In this paper, we introduce a workflow for modeling of fault reactivation with fault elements as gridblocks instead of surfaces. Reservoir simulation, with coupled fluid flow and geomechanics, was used for this purpose. The simulation models utilize a geomechanical module to capture elasto-plasticity and a compositional numerical scheme based on an equation of state (EOS) to calculate CO2-brine interaction. The geomechanical module used in this study is based on Hierarchical Single Surface (HISS) model that captures strain softening and hardening, and therefore post-yield plastic deformations related to fault reactivation. The compositional numerical scheme based on EOS calculates the amount of CO2 solubilization in brine as well as the density and viscosity of the CO2- and aqueous-rich phase. In this approach, the flow properties, i.e. permeability and porosity, dynamically change in response to geomechanical effects. The dynamic change was captured through a volumetric strain-permeability law.\u0000 Our simulation results show that the model is capable of capturing short-term evolution of fault reactivation and the resulting change of permeability along the fault. The dynamic changes of fault properties control the extent of fault reactivation, the pressure relief during injection, and the fault sealing capacity.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132639415","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}