Day 3 Fri, March 03, 2023最新文献

{"title":"Integration of Dynamic, Static and Seismic Models: Developing High Precision Target Drilling for Matured Fields","authors":"Rafidah Abd Razak, A. Chan, C. Pang, Jason Lew, Siti Hajar Zamridin","doi":"10.2523/iptc-22943-ea","DOIUrl":"https://doi.org/10.2523/iptc-22943-ea","url":null,"abstract":"\u0000 Ageing fields are often in a race against depreciating Net Present Value (NPV) and decreasing production, advent of rising water contacts threatening daily and cumulative production. Static geological models form the primary input model into dynamic models which define and determine the development strategy of fields. Typically, dynamic models built from incipient seismic and geological models comprising of well data from early appraisal wells. In time, incorporation of production data refines the dynamic behaviors of field and in turn, these dynamic models are then used for subsequent re-development of the ageing fields. However, the incipient seismic models rarely receive similar updates as seismic acquisition are too costly to justify in an ageing asset with ever-depreciating NPV.\u0000 This paper illustrates the process undertaken by subsurface team in identifying potential sites constraints by seismic and geological studies, in comparison with initial oilfield production incorporating pressure data to identify sweep efficiency. Starting with understanding a reservoir that experienced poor injection support, has led to unearthing the presence of faults that were not identified in previous seismic interpretations, and thus compartmentalizing the reservoir. The presence of the ‘unseen’ barriers in between an injector and an oil producer has hampered the injection effort towards the producer, and thus has been detrimental to the health of the reservoir.\u0000 In lieu of the renewed understanding of the reservoir with regards to field compartmentalization which is recognized as key threat to water injection performance in Reservoir-L, usage of artificial intelligence machine-learning generated fault volumes helped define compartments better. The results indicate the NNW-SSE conjugate (shear) faults formed during the Mid-Late Miocene times which were not clearly demarcated on earlier seismic, play key contributing role with regards to connectivity and intra-field communication. This in turn led to revised understanding on areas of reduced production that led to model updates in line with production behaviors.\u0000 Based on the new model, well location optimizations were undertaken for two water injectors in the infill drilling campaign for shallower Reservoir-K of Field S to avoid potential compartmentalization that would impact the sweep efficiency. Relocation of the water injectors into the same reservoir compartment as the target oil producer was expected to improve the EUR by ensuring direct sweep and good injectivity to the producer.\u0000 In summary, by revisiting field models in advent of updating and recalibrating the dynamic model in view of historical production data, the team was able to update the model contributing towards field revitalization and field management in ensuring the field model delivers to the field development plan. The hard work from the team has paid out through the recent production performance of the reservoir.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128642191","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 Engineering Solutions for Drilling Extended Reach Multilateral Wells with Lateral Sections More Than 2000 Meters with the Use of Mud Motor. Successful Experience in Tazovskoye Field","authors":"N. Abaltusov, Sergey Tensin, Mikhail Zibrov, Anatoliy Emshanov, Eldar Khayvarin, R. Sharipov","doi":"10.2523/iptc-23061-ms","DOIUrl":"https://doi.org/10.2523/iptc-23061-ms","url":null,"abstract":"\u0000 Rotary Steerable Systems (RSS) are, in general, more efficient versus Positive Displacement Motors (PDM) when drilling the wells under complicated geological conditions. Thousands of operations, performed all over the world, clearly confirm this statement (Wardana, R, 2019). However, this paper will demonstrate that there are geological features where the main advantage of RSS – drilling with constant rotation – is not efficient and may result in emergency situations.\u0000 Specifically, under such geological conditions it is necessary to drill in Tazovskoye field which is developed by extended reach horizontal and multilateral wells.\u0000 This paper will cover integrated engineering solutions, which made it possible to overcome geological challenges to reduce the costs of drilling extended reach multilateral wells by a deliberate engineered change from RSS to PDM application.\u0000 The approach was confirmed in 11 multilateral wells, drilled with the use of PDM. In this case the length of each horizontal hole totaled 2000 meters and more.\u0000 An all-time record was achieved in Russia in terms of the length of horizontal wells, drilled with PDM motors without using oil-based mud: a horizontal section 2,520 meters in length with DDI – 6.72, ERD – 2.67 was drilled.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"132 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116583138","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":"Study on Rotary Percussion Tool Parameters Optimization and Trial Test Evaluation","authors":"Tu Yulin, Bodong Li, G. Zhan, R. Rached, Eduardo Gramajo","doi":"10.2523/iptc-23005-ms","DOIUrl":"https://doi.org/10.2523/iptc-23005-ms","url":null,"abstract":"\u0000 Drilling in hard and abrasive formation represents a major challenge due to the low rate of penetration (ROP). Rotary percussive drilling tools take advantage of both the shear action of drill bit cutters and axial percussion energy to increase the drilling efficiency. Such tools have shown a significant benefit in drilling efficiency enhancement, especially in air drilling with an air hammer. This study focuses on a fluid-type rotary percussive drilling tool development and application to address the significant drilling challenge in drilling hard and highly abrasive sandstone formations. A rock mechanical study is carried out to get the compressive strength and the internal friction of the hard and abrasive formation. Then, a 6-3/4 inch rotary percussive tool is designed and optimized based on a relationship between rock mechanics and the output energy and frequency of the tool. Next, the tool was thoroughly tested in the workshop, and the key parameters were acquired and compared with the design.\u0000 The tool was trial tested in a hard and abrasive formation dominated by fine sandstone and siltstone in the upper section and a softer formation below. The new 6-3/4 inch tool was run in the test well and drilled DV tools, cement, float collar, and float shoe, then penetrated the hard and abrasive formation. The hammer drilled 912ft with an ROP of 10.5 ft/h with a pure drilling time of 87 hours. The ROP increase is around 30% for the same depth and formation with less WOB and RPM. Drilling efficiency was increased in the top section with less WOB and RPM compared with the same formation and depth of an offset well section drilled with hybrid bits. The differences of the wells in the hard abrasive formation thickness, bit type, BHA, bits dull grading, and RPM are studied. The tool performance evaluation and lessons learned from optimization and trial tests are summarized. The future direction of this work is also discussed.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"38 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125679814","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":"Drilling Optimization in Challenging Hard and Heterogeneous Sandstones using 3D Progressive Wear Simulation and Multiwell Data Learning","authors":"G. Zhan, William B. Contreras Otalvora, Xu Huang, Oliver Matthews, John Bomidi","doi":"10.2523/iptc-22976-ms","DOIUrl":"https://doi.org/10.2523/iptc-22976-ms","url":null,"abstract":"\u0000 Drilling is challenging in hard and heterogeneous sandstones because drill bits can experience excessive wear, leading to short footage. Consequently, choosing the correct bit via the accurate prediction of bit progressive wear and corresponding drilling response for pre-well and real-time is essential for drilling optimization. An advanced progressive wear prediction tool has been developed to overcome this challenge, which includes a multi-well data learning engine. A description of the individual cutting structure and its wear is included in the model, enabling optimization of bit designs and drilling parameters that reduce total well construction costs.\u0000 This work builds upon 3D drilling simulation at sharp or worn bit states. Progressive wear is included to simulate the evolution of wear flats with the distance drilled. The thermomechanical physics modeling is based on decades of cutting mechanics research and laboratory findings. To make this simulation tenable, a reasonable jump-in-distance was drilled, and corresponding wear was implemented based on incrementing the cutting location with the highest wear rate. The simulation is integrated into a multi-well learning engine for formation specific progressive wear model, using an evolution-based optimization algorithm. In the optimization process, the error metric included both drilling response error and the final wear area distribution error.\u0000 Corrected downhole drilling data and final dull state were processed for the multi-well data learning of the progressive wear model. The approach is first demonstrated on five runs in three different offset wells for pre-well optimization. The results obtained from the optimized performance on multiple offset training wells and the validation of the test runs achieved accurate prediction results. The pre-trained progressive wear model was then deployed in a real-time field trial. The results show the wear model successfully predicted both the progressive wear response and final dull state distribution in real-time for multiple field deployment tests with significant performance improvement. The error of the wear model prediction is smaller than IADC 0.5. The methodology implemented in this study demonstrates that physics and laboratory-based constraints imposed on the progressive wear model ensure that the model does not encounter overfitting and generalization issues during the data learning process due to the limited scarcity or bias in the training data.\u0000 This study presents a 3D representation of bit design, cutting structure details, and their progressive wear simulation in a holistic framework. The framework is applicable to challenging formations, where substantial amounts of data are not available for conventional data-driven models. The hybrid data-physics approach is leveraged to optimize the model parameters with runs from the available multi-well training dataset. This area-specific drilling response simulation with progressive wear is ","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"11 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130086356","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 Successful Fines Stabiliser Pilot Application in Arresting Severe Production Decline and Prolong Well Life","authors":"L. Hendraningrat, N. Ramly, L. Riyanto, S. Baharuddin","doi":"10.2523/iptc-23012-ms","DOIUrl":"https://doi.org/10.2523/iptc-23012-ms","url":null,"abstract":"\u0000 Fines migration is a recognized as one source of formation damage in oil and gas production wells. A newly fine stabilizers chemical was developed and applied to prolong oil well productivity by adhering the migrating fines to the pore surfaces and reducing the tendency for mobilization as observed in the laboratory. The paper presents the successful pilot application and monitoring process of newly developed fine stabilizer in an oil well with has a history of rapid decline after several times of stimulation.\u0000 A screening process to identify pilot well was carried out into well \"C\". The well was natural flow for almost 2 decades but in last 8 years, it showed a sharp oil productivity decline after several times workover (re-perforation). A series of experiments were performed to identify the root cause of the rapid decline of the oil well and concluded due to migrating clays. The newly fines stabilization chemical was developed which has a purpose to prevent detachment of those fines and prolong the formation structure integrity by keeping the fines stuck on the rock surface. The workflow breakdown design structure for injection and monitoring were carried out to ensure the well achieve the agreed objective that was to increase back production by reperforation job and to reduce production decline rate by 90% for the first 6 months and 30% afterwards.\u0000 As a first pilot, well \"C\" has the main target to delay the production decline after re-perforation due to fines migration as concluded based on root cause analysis of formation damage from comprehensive laboratory experiments. The novel inhouse fines stabilization chemical was introduced as damage remedial by neutralizing fines migration through microflocs and coagulated fines as solid. It was injected near the wellbore around 4-5 ft. and monitored for 6 months. The sampling was taken regularly to measure produced clay and sands and compared with the pre-treatment results. The particle size measurement showed if the produced particles decreased significantly. The post-treatment of fine stabilizer chemical shows that it can prolong oil well productivity by delaying the decline rate to 1.5%/month for 6 months monitoring period and even stable over 1 years, which means exceed the expectation.\u0000 The successful result of well treatment using newly fine stabilizers chemical has unlocked additional oil production and prolong well life.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"10 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114710521","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":"CO2 Prediction of the Undrilled Prospects of the Arthit Field via Geological-Informed Machine Learning","authors":"Nutchapol Dendumrongsup, Kittichote Veeranuntawat, Kasinee Suyacom, Chayapod Beokhaimook, Apsorn Panthong, Auranan Ngamnithiporn, Pitchaya Hotarapavanon, A. Ruangsirikulchai, J. Kaewtapan, Chittchon Chittpayak, Nuntanut Laoniyomthai","doi":"10.2523/iptc-23028-ms","DOIUrl":"https://doi.org/10.2523/iptc-23028-ms","url":null,"abstract":"\u0000 High Carbon dioxide (CO2) content presents a serious challenge in the development of Arthit Field. Accurate resource estimation, especially in the deep reservoir sections (Lower Miocene - Oligocene), depends on the accuracy of CO2 prediction. Formulated as a manual clustering approximation, conventional CO2 prediction requires intensive labor and fails to re-calibrate the model once the latest information is acquired. This paper introduces the application of machine learning concepts to the prediction of CO2. The proposed CO2 prediction methodology leverages machine learning techniques to enhance the understanding of a known field with existing CO2 concerns. Compared to the conventional manual clustering method, the machine learning model improves accuracy and reduces time and cost in the process of CO2 prediction and, in turn, resource estimation. Although our methodology is demonstrated specifically for CO2 in Arthit Field, it is equally applicable to other parameters and fields.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"217 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115964091","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":"World's First Advanced Dual ESP System Deployment for Harsh Environment","authors":"Abdulrahman Theeb Aldossary, Rusam Partadiwirya, Riza Tjahyadi Subijanto, Akram Mahmoud","doi":"10.2523/iptc-22813-ea","DOIUrl":"https://doi.org/10.2523/iptc-22813-ea","url":null,"abstract":"\u0000 A Dual ESP system is a redundant ESP concept that provides backup ESP system to be put on stream immediately if the primary ESP fails, which minimizes workover ESP replacement requirements and cost. An enhanced Dual ESP system for a harsh environment is installed to prolong ESP run life. These harsh environment Dual ESP system are equipped with full Metal-to-Metal Motor Lead Extension as well as H2S Scavenger seal sections on both upper and lower pumps to enhance their durability. Moreover, auto-check valves are included in the system to enhance dual ESP daily operation and maintenance. This paper will share the new dual ESP system design for harsh environments, enhancements, and successful applications in offshore fields.\u0000 Two identical, complete, and independent ESP systems are installed with standard Y-Tool (bypass system). All if which was achieved by installing the Metal-to-Metal Motor Lead Extension (MLE) Dual ESP application which acts as backup ESP system to be put on stream immediately after the primary ESP fails. Thus, avails the well potential and postpones the requirement of workover rig mobilization to replace failed ESP. Backup dual-ESP system extend overall ESP system run life in areas with limited rig availability.\u0000 The cutting-edge technologies that were deployed in this completion include:\u0000 Metal to Metal MLE on both lower and upper ESPs, which proved the increase in the run life compared to the standard MLE. Severe Service Seals (H2S Scavenger Seals), which protects the motor from corrosive subsurface elements. Dual Y-Tools to allow reservoir intervention below the ESP through bypass for logging, acid job and any Wireline / Coil Tubing jobs needed. Non-Return Valve (NRV) which facilitate auto switching between the upper and lower ESPs eliminating the costly offshore barge and wireline conventionally required to install isolation sleeves and blanking plugs. Dual penetration bore Aflas Packer which allows using two cable penetrators and has an Aflas material for sour applications.\u0000 This paper will provide in-depth information about each of the cutting-edge technologies deployed in this completion along with the added technical value of utilization. It will further provide the estimated significant cost avoidance achieved in offshore ESP fields following the deployment of this completion.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"72 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128900430","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 Systematic Approach to Fault Sealing Capacity Evaluation in Underground Gas Storage: A Case Study from China","authors":"Rujun Wang, Wei Zhou, Daiyu Zhou, Zangyuan Wu, Liming Lian, Gengping Yan, Guangqiang Shao, C. Zhang, Jun Li, W. Bian, Q. Jin, Zitong Zhao, Yong Zhang, Yantao Deng, Xingning Huang","doi":"10.2523/iptc-22981-ms","DOIUrl":"https://doi.org/10.2523/iptc-22981-ms","url":null,"abstract":"\u0000 Fault stability refers to the risk level of reactivation of the pre-existing fault in the stress field. Fault reactivation within the oilfield is mainly caused by the increase of fluid pressure in the fault zone. The quantitative evaluation index of the fault stability is the critical fluid pressure (that is, additional fluid pressure) required for fault reactivation under the current pore fluid pressure. When the formation pore pressure reaches the critical value, the corresponding fault part will be in the critical stress state. The sliding of the fault in the critical stress state will easily cause oil and gas leakage and casing damage at the edge of the fault. Therefore, it is of great significance to study fault stability for oilfield production. Ground stress is a key parameter for fault stability evaluation. There are many methods to calculate the geomechanics including hydraulic method, acoustic emission method, and the use of the logging data, among which the hydraulic fracturing method can be used to obtain the most accurate horizontal minimum principal stress. This paper calculates the continuous geomechanics by using the logging data. There are many methods available for evaluating fault stability, among which fault sealing analysis technology (FAST) method is most widely used. FAST can be used to not only quantitatively evaluate fault stability, but also evaluate the impact of fault cohesion on fault stability. There are many factors affecting fault stability. The relationship between the differential stress and tensile strength of the fault rock will affect the trend of the fault reactivation.The direction of the stress field also affects the fault stability greatly. The argillaceous material weakens the strength of fault rock. When a large amount of argillaceous material enters the fault zone, the fault tends to reactivate. The change of reservoir fluid pressure will also lead to the change of horizontal stress to affect the stability of the fault. In addition, the accuracy of seismic interpretation will also affect the evaluation results of fault stability. Based on the geological model framework and one-dimensional geomechanical model calibration, this paper establishes a three-dimensional geomechanical model by using the finite element simulation method to carry out four-dimensional geomechanical research to evaluate the fault stability in the development of the Donghe 1 Reservoir in Tarim basin. The research results show that the fracture sealing gradually strengthens during the development of Donghe 1 Reservoir, and the quantized critical fracture opening pressure is 67.38MPa.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"90 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128793634","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":"Minimising Reservoir Top Structure Uncertainty through Integration of Seismic Horizon Well-Tied Top Interpretation and Geosteering Distance-to-Bed-Boundary Calculation from Azimuthal Resistivity Tool: Case Study from Offshore Thailand","authors":"Numan Phettongkam, H. Ngo, A. Ruangsirikulchai, Ngamwilai Somwangsombat, Rutchanok Nasomsong, Saris Visessumon, Kampanart Jankham, P. Loviruchsutee, N. Gongsakdi, P. Chommali, Viktor Dovgopolyy, Jesús Rodríguez, Anis Sitthivanich","doi":"10.2523/iptc-23018-ms","DOIUrl":"https://doi.org/10.2523/iptc-23018-ms","url":null,"abstract":"\u0000 Reservoir top structure interpretation through seismic usually associated with uncertainty especially when sparse number of wells are available. This leads to uncertainty in gross rock volume and oil-in-place calculation. It is quite common with reservoir top interpretation picking varies significantly from optimistic to pessimistic case especially at the point distant away from wellbore.\u0000 This paper integrates the geosteering distance-to-boundary (DTB) calculation from horizontal well drilling to minimize the uncertainty window of top interpretation from surface seismic to deliver more accurate remaining oil-in place.\u0000 During the geosteering operation, seismic horizon interpretation of reservoir target sand with multiple scenarios in offshore field was compared with the distance to boundary calculation that map the reservoir top structure with azimuthal resistivity tool. Prior to geosteer horizontal well in the oil-rim reservoir after long production, pilot hole was drilled to update the current fluid contact. Reservoir top interpretation is revised by including horizon top structure tied to well data from the pilot hole and existing wells in the area.\u0000 The revised top structure which includes the pessimistic and optimistic case generally has significant difference in remaining OIP. Upon geosteering horizontal well, DTB calculation from azimuthal resistivity tool was capable to map the top reservoir boundary in real-time with reference from the seismic top interpretation from heel to toe of the lateral with good quality mapping of entire top reservoir structure.\u0000 Distance to boundary (DTB) with good quality of top reservoir structure mapping throughout the section tracked closely to optimistic case of seismic top interpretation of target sand. Geosteering with azimuthal resistivity with RSS directional tool mapped the top of the reservoir on the upside and OWC from the downside up to 4.8 m away from the tool. As the top is expected to dip down and intersected the trajectory at multiple scenarios, the mapped boundary provided insights of gentle dipping trend, suggesting the top of reservoir could extend laterally longer than pessimistic case. With the result closer to optimistic case, the calculated remaining OIP volume calculated was on the optimistic side with significant difference, larger volume, from pessimistic case of OIP calculation.\u0000 Integration of seismic top interpretation with geosteering distance to boundary application in lateral well could minimize the uncertainty in reservoir top horizon interpretation. The workflow enabled to place the well in the sweet spot while managing the uncertainty of top structure. With production from horizontal well, the well production rate is expected to increase to 2900 BOPD for initial oil production compare to below 1000 BOPD prior to horizontal well drilling. This workflow could be applied for future lateral well with high uncertainty of the target to place the well in sweetspot for field life e","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"142 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123395041","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":"Business Intelligence Platform Applied to the Interdisciplinary Management of Subsurface Data Integration","authors":"C. Sanasi, M. Amicosante, D. Mezzapesa, F. Marfella, Riccardo Pagani, E. Gentile, Alessandro Bucci, A. Crottini","doi":"10.2523/iptc-22962-ea","DOIUrl":"https://doi.org/10.2523/iptc-22962-ea","url":null,"abstract":"Over the last 3 years, Eni has developed an integrated platform to gather subsurface data and make them available to the final users across the company. The Platform is structured in four data domains including the well data, which is the focus of this abstract. In the data model, the well master and architectural data assume paramount importance since they are upstream of the value chain and represent the aggregator of all the data recorded in the well. A large amount of data coming from all Eni Affiliates and operative sites is produced daily. To gather, perform Quality Controls and ingest them, Eni has implemented a governed workflow to ensure data is made available to the final users through the platform in an efficient and transparent way.\u0000 The workflow aims to ingest the well master and well geometrical data directly from the well site defining roles all along the data transmission chain, with the ultimate objective to ensure the proper data quality once they reach the cross-functional subsurface data platform. It is no less important the timely availability of such data to guarantee a prompt association with geological and drilling log data. Given the increased amount of data acquired from disparate data sources, different functions and locations, Business Intelligence tools have been designed to monitor the workflow combining data for an easier data insight. To manage such complex network, dedicated dashboards allow all the users involved to visualize the status of the processes through specific KPIs, thus optimizing communication and reducing the human effort required.\u0000 The capability to manage, validate and quickly interpret data will determine the competitive advantage among Energy Companies in the next future. Eni targets to excel in the everchanging business environment leveraging the new century asset: the data.\u0000 The presented approach, combined with the diffused data culture initiatives, promotes a collaborative environment, and increase awareness on data importance across the value chain.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126386717","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}