Day 3 Wed, March 22, 2023最新文献

{"title":"Agile Approach to Mitigate Corrosion and Scaling Issues in Unconventional Vaca Muerta Wells","authors":"Maximiliano Giraldo, Maria Begoña Garcia, Magali Pasini, Juan Ignacio Sosa, Adrian Muñoz, Facundo Siviero, Andres Mazo","doi":"10.2118/212575-ms","DOIUrl":"https://doi.org/10.2118/212575-ms","url":null,"abstract":"\u0000 During well-work to install artificial lift in unconventional horizontal wells in El Trapial field, scale and corrosion were identified in two different pads. The West pad had been on production for fifth teen (15) months prior the intervention while the East pad had nine (9) months online. An interesting observation during the inspection of the carbon steel tubulars was that most of the corrosion was located on the lower section of the string but chrome (Cr) 1% chemical injection mandrels were not affected. Based on the samples analyzed, the corrosion was associated to high carbon dioxide (CO2) partial pressure and acidized water production while the scale samples confirmed it was barium sulfate (BaSO4). Both conditions are detrimental to the well integrity and productivity, highly impacting the operating cost to resolve them. As the full field development is the next phase under factory execution design, it was critical to rapidly incorporate these learnings and generate an effective mitigation plan.\u0000 Applying a traditional project management approach would have delivered a working solution but probably not on time and with low tolerance to unanticipated changes. Agile framework is an alternative methodology that initially started in the software development industry and centers around four values: 1) Individuals and interactions over processes and tools 2) Working software over comprehensive documentation 3) Customer collaboration over contract negotiation 4) Responding to change over following a plan. These values promote a mindset that enables transparency within the team and stakeholders, prioritizing value adding work, adaptability, frequent integration of feedback, self-organizing teams, and continuous improvement of the product. Based on recent successful applications of this approach in other projects, the multidisciplinary team decided to work in an Agile framework to accelerate the solution for the upcoming development well’s design.\u0000 Following adapted Scrum ceremonies, within 5 Sprints of 2 weeks each, the team simulated fluid velocities in different tubing sizes, corrosion rates varying tubing size and metallurgy, modeled drawdown strategies, and assessed materials lead time and incremental costs. Ultimately, the team generated effective short- and long-term solutions despite unexpected deviations along the process: replicate successful drawdown management of appraisal wells to control high initial pressures, change tubular metallurgy from carbon steel to chrome alloy, transition from initial tubing flow to casing flow while well natural capacity allows it, install artificial lift with 2 3/8\" tubulars and inject solid scale inhibitors during the initial hydraulic fracturing stimulation of the wells.\u0000 This paper will cover how the methodology of the Agile process was applied, the technical work generated and final recommendation of this alternative approach to manage a project.","PeriodicalId":242465,"journal":{"name":"Day 3 Wed, March 22, 2023","volume":"51 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124742890","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":"Fracture Identification and Classification Using the Resistivity Image Logs in Tight Conglomerate Reservoir: A Case Study from Junggar Basin","authors":"Xin Meng, Zhen Yang, Jixin Gao, Bowen Liu, Leipeng Wei, Xu Zhang, Bo Liu, Meng Zhao, Wei Wang, P. Delgado","doi":"10.2118/212437-ms","DOIUrl":"https://doi.org/10.2118/212437-ms","url":null,"abstract":"\u0000 The conglomerate reservoir with a very low porosity and permeability is one of the most important reservoirs in Northwest China. The pay zones are very difficult to be identified in a conglomerate reservoir which is more than 200 meters thick, because there is no any clear positive response in the open-hole logs. It is challenging to evaluate this kind of tight reservoir using the traditional methods. Identifying and evaluating fracture zones in a fractured conglomerate reservoir were the objective of this case study. The high-resolution resistivity image logs were widely acquired on the key wells in this research area. Based on image interpretation and core calibration, a fracture quality evaluation method was proposed and applied in this conglomerate reservoir.\u0000 Traditionally, the natural fractures on wellbore resistivity image are divided into two types: conductive or resistive fracture depends on it is \"white\" or \"dark\". Typically, conductive fractures filled with mud are open fractures, while resistive fractures are half-open or sealed and filled entirely or partially with calcite cementations. Based on core observations and descriptions, the core images and wellbore images were well-matched. The fractures picked from wellbore images are all calibrated with the core images.\u0000 In this case study, the fractures were classified in three types: open, half-open, and sealed. The half-open fractures were mainly identified based on the angle between the fracture strike and maximum horizontal stress direction. The fractures were mainly resistive fractures in the study area.\u0000 Not all resistive fractures are sealed. They may be half-open when the fracture strike has a low angle with maximum horizontal stress. The test and production data validated the selection of formation \"sweet spots\" with good fracture quality and identified where stimulation of half-open fractures could improve production significantly. The production data showed that half-open fractures can be the target zone in tight conglomerate reservoirs.","PeriodicalId":242465,"journal":{"name":"Day 3 Wed, March 22, 2023","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122709836","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":"Child-Child Fracture Driven Interactions Analysis and their Application with Field Case Studies","authors":"M. Weimann, Yann Facundo d'Huteau, Cristian Abel Paladino","doi":"10.2118/212411-ms","DOIUrl":"https://doi.org/10.2118/212411-ms","url":null,"abstract":"\u0000 For unconventional shale reservoirs, understanding the relationship between well spacing, fracture dimensions and extensions are key components for achieve optimal oil and gas production without leaving undrained areas. The analysis of Fracture Driven Interactions (FDI) will contribute with this understanding. Pressure interference data, in a pad with several new wells (child-child) or between parent and child pads (parent-child), are obtained with gauges connected at the wellheads that record pressure continuously, while the sequence of hydraulic stimulations is carried out.\u0000 Following the development of unconventional fields in Argentina, this type of information has been acquired more frequently and has become more relevant for the characterization of the different subsurface effects going on between adjacent wells (parent and child-child) during fracturing.\u0000 These pressure connections between active and passive wells are not necessarily negative, and a certain level of communication may be desired since the total absence of interaction could be interpreted as volumes of rock unstimulated and, therefore, unproduced. Part of the initial process described in this work involves the steps to collect and process, simply and efficiently, all the child-child interaction data; to generate a reliable database that can be analyzed and integrated with other field observations.\u0000 In this work, we present case studies where the child-child FDI data were analyzed using different tools, with the main objective of characterizing the hydraulic fractures generated with different stimulation designs and understanding their relationship with the vertical (different landing) and horizontal (same landing) spacing. Also, we present cases showing examples where child-child interferences are integrated with other field data acquisition (chemical tracers, microseismic, etc.) to improve and complement the understanding of the subsurface effects occurring during hydraulic fracturing operations.\u0000 Finally, the main conclusions are:\u0000 Stronger interferences were detected between wells located in the same landing zone, and vertical interactions tended to be weaker. The depletion regions from parent wells have an influence on the FDI responses between child wells. The \"parent-child\" condition produced irregular responses on the child-child FDI that are interpreted to be associated with possible asymmetrical growth of the fracture lengths. Fluid volume per cluster (fracture design parameter) shows a relevant impact on the child-child FDI responses, demonstrating that this variable is an important driver for these interferences. Cocina wells tend to have more and stronger interactions (longer fracture lateral growth or more interconnection among natural fractures) that the Lower Organic ones. Data integration between child-child FDI and other data acquisitions (e.g., chemical tracer and microseismic) helps to understand and conclude about subsurface characteristics.","PeriodicalId":242465,"journal":{"name":"Day 3 Wed, March 22, 2023","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114374237","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 Geo-Engineering Integrated Technologies for Ultradeep Longmaxi Shale Gas Life Cycle Management, Sichuan Basin","authors":"Liwei Jiang, Chunduan Zhao, Jun Peng, Lipeng Wang, Chenglin Liu, Qingshan Li, Yongjie Huang, Bowen Cao, Hong Tian","doi":"10.2118/212407-ms","DOIUrl":"https://doi.org/10.2118/212407-ms","url":null,"abstract":"\u0000 A huge variation in well performance was observed in Longmaxi shale gas wells, in Yongchuan block, Sichuan Basin. The Longmaxi shale was buried deeper than 3500 m with complex structures, in-situ stress, and natural fracture corridors, which makes well performance very uncertain. Horizontal well length was greater than 2000 m and proppant intensity was higher than 3.5 t/m.\u0000 To solve these challenges in an ultradeep shale gas play, a multidisciplinary and life cycle management strategy was proposed and practiced. Initially, geology and geophysics (G&G) work using seismic data revealed the exact geological structures with folds, faults, and natural fractures. Then the study turned to 3D high-resolution geological and geomechanics modeling to identify the sweet spots and high drilling and completion risks areas. With the deep G&G understanding, the well drilling and completion design were proposed, executed, and iterated by onsite diagnosis and support to place high-quality hydraulic fractures. Finally, the production strategy was optimized to keep the flow path undamaged during its life cycle.\u0000 The detailed study and post-fracture well performance indicate that the successful ultradeep shale gas development in the Longmaxi in the Sichuan Basin relies on:\u0000 Placing the wells where there are fewer faults but more natural fractures Identifying the stages with high screenout and casing failure risks, thereby levering the 3D G&G model Creating the completion design by considering the screenout and casing failure risks Executing the completion design successfully by onsite diagnosis and support, leveraging on the 3D G&G model, microseismic data, and treating pressure trend Enhancing the 3D model accuracy by iterations with observation data Minimizing the propped fracture damage by adjusting the choke size during the production phase\u0000 With the high-resolution quality management on well drilling, completion, and production management, the well outperformed 100% more than the neighboring wells. The geoengineering integration values were highlighted in both the in-house study and field operations, and this strategy could be duplicated to other candidates approaching their drilling, completion, and production engineering's limits under complex geological conditions.","PeriodicalId":242465,"journal":{"name":"Day 3 Wed, March 22, 2023","volume":"21 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134331627","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 Total Organic Carbon (TOC) Prediction for Vaca Muerta Shale","authors":"Rahimah Abd Karim, R. Aguilera, Camila Fraga, Laura Estela Toledo","doi":"10.2118/212422-ms","DOIUrl":"https://doi.org/10.2118/212422-ms","url":null,"abstract":"\u0000 TOC evaluation in Vaca Muerta is challenging due to its complex mineralogy and depositional settings. Laboratory measurements can be affected by sample preparation, especially for wells drilled with oil-based mud. Empirical methods like Passey ∆log R relies on resistivity as one of the inputs, which can be affected by clay and mineralogy in shale. In this study, an improved TOC prediction using a multiple regression equation is proposed. The findings reflect the vertical variability of TOC.\u0000 The method developed in this study first evaluates the TOC correlation with available electrical logs from a vertical well that includes spectral gamma ray, neutron porosity, density and resistivity. It also assesses the correlation with clay and inorganic mineralogy available from X-ray diffraction. This study also incorporates for the first time, thin bed heterogeneity that comprises calcite beef, ash beds and nodules. They make up a considerable portion of the facies, especially in the organic-rich unit of Lower Vaca Muerta (LVM). Despite the complexity, the modelled TOC calibrate well with the laboratory-measured TOC.\u0000 The TOC regression equation is developed based on two key findings. First, the TOC is positively correlated with uranium and resistivity; and negatively correlated with dolomite and calcite. High TOC is observed in low Ca (calcite, dolomite and ankerite) and high QFP (quartz, k-feldspar and plagioclase) intervals, and vice versa. This negative correlation is unique to Vaca Muerta, which is attributed to the mixed carbonate-siliciclastic depositional system (Kietzmann et al., 2014). Second, the TOC is also strongly affected by thin bed heterogeneity that is identified through micro-resistivity image log and high-resolution logs. Their effect is more pronounced on resistivity log; therefore, an adjustment factor is applied to the regression to account for their presences. Results show that the modelled TOC match well the core TOC as compared to Passey ∆log R method. An important observation is that the Passey ∆log R technique would overestimate the TOC at the top of Upper Vaca Muerta due to high and resistive Ca content; and underestimate it in LVM due to conductive clay in the argillaceous ash beds. Consequently, it would mislead the estimation of reservoir thickness, identification of sweet spot for landing zones, as well as resource estimation in Vaca Muerta shale.\u0000 This paper develops an original regression equation that models TOC in the presence of thin bed heterogeneity in Vaca Muerta. The results compare well with the laboratory-measured TOC. The study reveals the vertical variability of TOC across the five stratigraphic units in a vertical well. More importantly, it highlights potential TOC discrepancy by Passey ∆log R technique that could mislead reservoir thickness estimation due to the effects of mineralogy and thin bed heterogeneity on resistivity.","PeriodicalId":242465,"journal":{"name":"Day 3 Wed, March 22, 2023","volume":"137 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127862799","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":"3D Integrated G&G Model-Driven Mitigation Workflow on Screenout, Frac Hits and Casing Deformation in Ultradeep Shale Hydraulic Fracturing","authors":"Jian-fa Wu, B. Zeng, Lipeng Wang, Haoyong Huang, Yuanwei Pan, Yi Song, Herick Nunez, Qi Deng, Lizhi Wang, Haipeng Zhao","doi":"10.2118/212406-ms","DOIUrl":"https://doi.org/10.2118/212406-ms","url":null,"abstract":"\u0000 The Longmaxi shale gas play in Sichuan, China is unique due to multiple tectonic deformations in the geological history, which makes the shale play highly heterogenous and hydraulic fracturing execution problematic. The hydraulic fracturing design has matured after ten years’ evolution. However, it could not ensure every well's success without considering heterogeneity. Screenout, fracture hits, and casing deformation are still very common because informed decisions cannot be made ahead of operation or in real time. These risks should be recognized and in turn mitigation measures could be proposed through deep understanding of the geological and geomechanical characteristics.\u0000 To address these challenges, a multidisciplinary team was formed to work on a pad. The geological and geomechanical (G&G) context was first determined by 3D G&G modeling. Then a survey was completed on the whole block to determine the root causes of screenout, frac hits, and casing deformation, and high-risk areas or stages were identified. Based on this, the proposed mitigation included adjusting perforation design, pump rate, fluid volume, and fracture sequence. The effectiveness of mitigation measures and the 3D G&G model were validated and iterated by onsite fracturing diagnostics.\u0000 Through the above efforts, the designed proppant volume achieved zero casing deformations, fewer screenouts, and weaker fracture hits. This was the first pad with zero casing deformations across the whole block. The key findings were proved to be effective and could ensure success of hydraulic fracturing in the study pad of ultradeep Longmaxi Shale:\u0000 The natural fracture corridors were the main cause of screenout. The possible bedding plane open and bad fracture initiation could be other causes of screenout. The natural fracture was the main cause of fracture hit and the connection among hydraulic fractures was the second cause. Adjusting the zipper fracturing sequence to interfere with hydraulic fracture propagation could help weaken it. Unstable natural fracture was the main causes of casing deformation in the Luzhou Block. Adjusting the fracturing sequence and fluid pumping intensity could mitigate casing deformation. The key to effective mitigation was continuous 3D G&G modeling through ongoing iterations with field data.\u0000 Finally, a model-driven workflow was developed for hydraulic fracturing design and execution, which could be a resource for other shale plays with similar challenges worldwide.","PeriodicalId":242465,"journal":{"name":"Day 3 Wed, March 22, 2023","volume":"134 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123435747","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":"Proppant Screen-Out During Re-Fracturing Caused by Damage of Heavy Mud in Existing Fractures: Case Study and Solutions","authors":"Huifeng Liu, Zhixiong Xu, Z. Yuan, Haochen Han, Zhiming Wen, Jianbo Li, Lu Song","doi":"10.2118/212401-ms","DOIUrl":"https://doi.org/10.2118/212401-ms","url":null,"abstract":"\u0000 The reservoir pressure coefficient is over 1.80 in the Kelasu foreland area in western China. Heavy mud weighted by ultra-micro barite is used to kill the well for downhole operations. For the wells that have been fractured, the mud easily leaks into the fractures, bringing barite weighting agent into the existing fractures and damaging the well productivity. Re-fracturing is conducted in order to recover the well productivity, but abnormal pumping pressure and proppant screen-out is frequently encountered.\u0000 Three typical wells that have encountered such problems were analyzed by construction data comparison and using the fracturing simulator StimPlan. The root causes were firstly theoretically analyzed and then laboratory tests were also carried out to verify our theoretical deductions. The comparison results show that the pressure for fracture extension during re-fracturing of the three wells is 20%-40% higher than the initial fracturing; the leakage of the heavy well killing fluid weighted by ultra-micro barite during downhole operations was the main cause of the abnormal pumping pressure and the proppant screen-out during re-fracturing.\u0000 The laboratory test results showed that the properties of the ultra-micro barite well killing fluid is relatively good after rolling for 15 days under high temperature, but its density and rheological parameters tend to decline due to barite sedimentation; the invasion of the heavy well killing fluid into the matrix reduced the Young's modulus by 3%-5% but increased the Poisson's ratio by 102.42% maximally, which would consequently reduce the dynamic fracture width and lead to abnormally-high pumping pressure and proppant screen-out during re-fracturing. The damage of the heavy well killing fluid to the existing propped fractures was also serious. It reduced the propped fracture permeability by 50%-80% and the retained barite in the fracture was difficult to displace out.\u0000 Several solutions have also been provided for wells with potential heavy mud damage. In high pressure wells where high-density well killing fluid has to be used during workover, acid-soluble solid is better to be used as the weighting agent. Besides, the re-fracturing pumping schedule should be designed with more and small proppant concentration stages if the well has been damaged by heavy mud so as to avoid screen-out. A barite removing agent was developed to remove the damage caused by barite weighting agent, which can be used for barite removal before hydraulic fracturing so as to avoid abnormal pumping pressure and proppant screen-out. The use of this agent in well BZ-D significantly mitigates the pumping pressure during re-fracturing, and a production increase of 131% was obtained.\u0000 This paper digs into the impact of heavy mud residue on fracturing extension during re-fracturing through well case study. A method of avoiding abnormal pumping pressure and proppant screen-out, using barite dispersing and chelating agent before re-fractu","PeriodicalId":242465,"journal":{"name":"Day 3 Wed, March 22, 2023","volume":"21 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132766771","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":"Fracture Design Optimization Utilizing 3D Simulation Models & Sensitivity Analysis for Unconventional Reservoirs","authors":"Esan Shoostari, M. Watson, S. Gorell, Y. Kocoglu, Ali Yousef Taqi, Hao Zhang","doi":"10.2118/212581-ms","DOIUrl":"https://doi.org/10.2118/212581-ms","url":null,"abstract":"\u0000 Hydraulic fracturing is the gateway for achieving new levels of unconventional resource production. However, hydraulic fracturing requires careful planning and optimized design for it to be profitable. There are multiple parameters that affect the performance of a hydraulic fracture design. One of the most important parameters that effect the performance of hydraulic fracturing is the fracture cluster spacing (FCS). FCS design is a complicated task especially for a new area due to the complexity of rock mechanics involved in unconventional reservoirs. We developed a novel sensitivity analysis approach to optimize the FCS using a 2D and 3D hydraulic fracturing models built with field data acquired from a well producing in the Eagle Ford. Our optimization criteria include fracture conductivity, fracture cluster length, fracture cluster width, proppant coverage, and fluid loss. The main optimization constraint during the fracture design was to avoid stress shadowing effects and screenout issues. This approach consists of two phases. Phase 1: Investigation of optimum clusters per stage number. Phase 2: Creation of the optimum fracture design. First step in our methodology is generating the simulation model by importing the log data to distinguish potential pay zone(s) and calculate the stress profile of these zone(s). Second step is to build a permanent 2D simulation model by selecting a perforation design, optimum proppant size, proppant type, pumping rate, and fluid type to finally attain an injection schedule for the 3D model. The final step is to optimize the 3D model’s performance by selecting the ideal FCS per stage. Our results show that the optimum cluster design is 3 fractures per stage with 200 feet spacing between fracture clusters (FCS). We observed that most cases outside the optimum design will cause stress shadowing which needs to be avoided for the sake of fracture efficiency and well productivity. Although, this FCS design is for a specific area, our comprehensive sensitivity analysis approach will be a guide to many operators to design fracture jobs more efficiently in the future because stress shadowing can happen for any area in the world. Our optimization study also revealed that we can get an efficient hydraulic fracture design with low number of clusters which will have a positive impact on the environment due to water preservation. It will also reduce the cost of the operation and the time it takes to complete the fracture job.","PeriodicalId":242465,"journal":{"name":"Day 3 Wed, March 22, 2023","volume":"49 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134241519","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 Advance Modelling Techniques to Design Diversion for Acidizing, Fracturing & Re-Fracturing","authors":"M. Omer, F. Fragachán","doi":"10.2118/212415-ms","DOIUrl":"https://doi.org/10.2118/212415-ms","url":null,"abstract":"\u0000 Stimulation fluids injected into a reservoir generally take the path of least resistance, i.e., zones of high permeability where often the stimulation is not as important as other critical under-stimulated areas. This leads to under-stimulated zones, which negatively impacts the production, or over-stimulated zones, which might lead to softening of the wellbore rock and, with time, might have also a negative effect on production. The efficiency of a fracturing, acidizing, or re-fracturing treatment depends on maximizing its contact with the zone of interest and uniform distribution in the reservoir. To achieve this goal, existing fluid paths must be efficiently and temporarily blocked, therefore diverting the treatment towards under-stimulated areas, a process known as diversion. The main goal of diversion is to distribute the stimulation fluid across the reservoir uniformly.\u0000 An analytical model based on computational fluid dynamics and discrete element modelling has been developed to optimize the different parameters that affect an optimum diversion. The parameters that effect the efficiency of plugging are flow rate, PSD (Particle Size Distribution), concentration, carrier fluid, and the displacement rate during diverter injection. The modelling can be customized depending upon the type of application.\u0000 This paper will summarize an engineering workflow to optimize diversion design and present successful cases globally of biodegradable, bi-particulate diversion applications in matrix acidizing enabling a production increase of 140%, re-fracturing applications (which led to the formation of new fractures in the new zones not previously stimulated), and uniform fracture growth from horizontal wells.\u0000 We believe that an engineering approach is critical to the success of matrix acidizing, fracturing, and re-fracturing. The results demonstrate the effectiveness of advance modelling and bi-particulate diverters in minimizing the formation damage, evenly distributing the stimulation fluid, and thereby increasing its effectiveness and retarding the softening of rock, and to enhance the production across the target zone. The lessons learned from various applications of these engineered bi-particulate diverters can be applied for stimulation design and planning","PeriodicalId":242465,"journal":{"name":"Day 3 Wed, March 22, 2023","volume":"662 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121996591","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":"Development and Application of Layer Intensity Index Based on Image Logs in Lacustrine Shale Oil Formation-A Case Study from Sichuan Basin","authors":"Jing Hao, Xin Luo, D. Yu, Shu Hong Liao, Keli Hou, Yue Wang, Xianran Zhao, Bo Liu, Meng-shi Zhao, J. Wu, Jing Mo","doi":"10.2118/212431-ms","DOIUrl":"https://doi.org/10.2118/212431-ms","url":null,"abstract":"\u0000 Lacustrine shale oil is the hottest recent topic in the main basins of China. To better understand the reservoir controlling factors, operators acquire borehole images, nuclear magnetic resonance (NMR), and geochemical logs, which help them identify the sweet spots in shale oil formations. These reveal that that the layering textures have a close relation to key reservoir parameters, such as porosity, and total organic carbon (TOC), etc.\u0000 The objective of this study is to develop and apply a \"layer intensity index\" method to the lacustrine shale oil formations of Sichuan Basin. To do this, we developed a quantitative estimation workflow based on borehole image processing, and obtained a \"layer intensity index\" after image flattening, binary processing, and horizontal edge detection on resistivity image logs. With calibrations of core data, the layer intensity index can reflect the degree of layer development in the shale oil formation. Based on this parameter, the shale oil formation could be classified into three categories based on this parameter: highly layered zone, medium layered zone, and massive zone.\u0000 In this study, the typical shale oil zones are identified based on the integration of the layer intensity index and other key petrophysical parameters. A good shale oil zone has relatively high layer intensity, TOC, porosity, and clay content. In this study we found that the layer intensity index is well-correlated with the effective porosity (PHIE) and TOC. Finally, the high TOC, high effective porosity, and highly layered pay zone is recognized as sweet spots of the shale oil reservoir. The evaluation result was then provided to the operator for horizontal well drilling design.\u0000 The layer intensity index was obtained using an innovative process workflow in the lacustrine shale oil formation of the Sichuan Basin. This quantitative layer intensity analysis has enriched the application of resistivity image logs and could be widely used in other similar shale oil reservoirs.","PeriodicalId":242465,"journal":{"name":"Day 3 Wed, March 22, 2023","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132024552","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}