Day 1 Tue, August 09, 2022最新文献

{"title":"A Successful Water Shut Off using a Thixotropic Treatment in a Sub Hydrostatic and Highly Aromatic Well, Results in Increased Gas Production of 30% and Reduced Water Production of 63%, Vietnam","authors":"Tuanangkoon Daohmareeyor, T. Nguyen, Reawat Wattanasuwankorn, Young Sig Kim, Tan Khoa Nguyen","doi":"10.2118/209889-ms","DOIUrl":"https://doi.org/10.2118/209889-ms","url":null,"abstract":"\u0000 An offshore operator in Vietnam faced high water production in a sub-hydrostatic and highly aromatic gas well. In addition to low productivity, the high water cut also strained the water treatment facility. Previous treatment attempts to shut off the high water-producing zones have been unsuccessful due to challenging well conditions.\u0000 [EB1]With the treatment facility reaching maximum capacity, and expansion of the water treatment capacity being a time-consuming and costly option, a subsurface well intervention was chosen as the most effective way to reduce water production from the well. The well had complex reservoir characteristics due to highly depleted zones that made treatment placement even more complicated, increasing the risk for the operation. The well produces aromatics, and using packers for isolation reduces the packer element sealing performance. Due to the high deviation angle, a Thixotropic Organically Crosslinked Polymer (TOCP) was designed and pumped for the high water-producing zones.\u0000 A customized solution using a TOCP with extensive laboratory testing was found to be the most suitable treatment design for this well. The new placement technique provided prevention of losses to the depleted zones. The thixotropic treatment provided higher viscosity when pumping stopped, allowing the polymer to seal off at the target zone. As a result of the treatment, the well responded positively. The operator significantly reduced produced water from 5,000 BPD to 2,000 BPD, accommodating the capacity of the water treatment facility. Meanwhile, gas production also increased from 4.6 M SCFD to 6.1 M SCFD, reducing the possibility of the well getting loaded up during platform shutdown.\u0000 The careful engineering design and laboratory testing played a significant part in the successful campaign, with collaboration from the operator and service company leading this campaign to be a successful project. This approach and solution can help enhance production performance and reduce the cost associated with water production.","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"46 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130019787","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":"Advance Nuclear Magnetic Resonance and Image Logs Application for Predicting Particle Sand Distribution","authors":"E. Samuel, Mohd Shah Redza Hanif, Muhd Syaiful Azman Mustapa, M. Adeyosfi, M. M. Lwin, S. Lee, P. Millot, F. K. Wong","doi":"10.2118/209912-ms","DOIUrl":"https://doi.org/10.2118/209912-ms","url":null,"abstract":"\u0000 The complexities of designing an effective sand control for unconsolidated gas reservoirs in a deepwater environment is exacerbated when the targeted formation sands are characterized by particle size distributions with poorly sorted and non uniform coeficients, and high fine concentrations. Managing these intricacies requires comprehensive sand retention studies developed to ascertain the effectiveness of the sand control performance of gravel and screen gauge opening combinations in the presence of selected formation sand ratios. To build a representative testing program, actual core samples from the targeted studied zones are desirable. However, for economical, technical or logistic contrains the availability of these cores is not always feasible. This paper covers a workflow to determine a synthetic Particle Size Distribution (PSD) of a targeted well in a development block where no core data is available. The data feeding the workflow is derived from wireline bore hole imagers and Non-Magnetic Resonance (NMR) logs obtained from six wells drilled in the exploration phase of the studied gas block. Results are calibrated with localized PSD from available side wall cores. Furthermore, data obtained from the process is used to interrogate sand retention testing Mastercurves built with formation samples from one of the fields in the studied block (Field I). The interrogation process takes the synthetic PSD from the targeted well and creates normalized formation testing ratios which are then compared to the results documented on the sand retention Mastercurves. This paper is intends to discuss the worklflow and results of its field application.","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121348240","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":"Complete MPD Rig: Time for Jack-Ups Now","authors":"B. Gedge, C. Binh, T. Vuong, Nguyen Hai, Norman Yaw, J. Mardon, Herbert Frohlich, Neil Gooding, H. Santos","doi":"10.2118/209890-ms","DOIUrl":"https://doi.org/10.2118/209890-ms","url":null,"abstract":"\u0000 Four years ago (IADC/SPE-191099) the move was clear on floating rigs​; to have them fully equipped with a Complete MPD package, the economic justification was very strong. Currently, there are around 20 floating rigs with a Complete MPD package, permanently installed. For Jack-Ups, however, the same move started only recently, with a few rigs now equipped with a Complete MPD package, using the same philosophy applied to a floating rig. The paper initially describes the success obtained by the Complete MPD​ floating rigs, not only from an economic, but also from a technical point of view, with operations in Australia, Brazil and the Gulf of Mexico. Having the MPD package permanently installed and ready to use, operators are now deploying MPD for the total well construction process, with a rig crew competent in running the MPD system, from spud to the T.D. of the well. This includes running casing/liner, cementing and, also, completions. The paper outlines the benefits and advantages for both the operators and drilling contractors, showing they are significant. Companies are taking advantage of having the MPD system on the rig and being able to maximise the full benefits.\u0000 With all the success seen on floating rigs​, operators start​ed to realize the benefits of using the same approach for Jack-Ups, building on previous experience with temporary MPD installations on Jack-Ups, ​learning from what worked and what did not work. The paper de​scribes the recent Complete MPD Jack-Up installation in Norway ​(implemented under the new MPD NORSOK requirements, which made it even more challenging​), the success achieved with the first wells drilled, and how the economics will work for the Jack-Up market, in the same way it works for the floater market. The technical benefits are the same, as the system used on the Jack-Up is equivalent and has the same features of the systems used on the floating rigs.\u0000 The paper finally addresses the Asia Pacific market, which is dominated by Jack-Up rigs over floaters. The economic, technical, HSE and logistical benefits make it an appealing proposition to have a Complete MPD Jack-Up rig, and they are all discussed in detail. An example is used with a Jack-Up operating in the region, clearly demonstrating its similarity to a floating rig when adopting the same Complete MPD Rig approach.","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"44 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129665175","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":"First Slim Open Hole Standalone Screen Completion Offshore Malaysia – Performances, Lessons Learned and Way Forward","authors":"Suman Kumar, W. M. F. W. Hassan, Nurlizawati Latif, C. H. Roh, B. Madon, M. Z. Sakdilah, Aminuddin B Karim","doi":"10.2118/209855-ms","DOIUrl":"https://doi.org/10.2118/209855-ms","url":null,"abstract":"\u0000 T field has very unconsolidated sand with high nonuniformity and high fines contents in H and I sands and require robust sand control, typically Internal gravel pack (IGP). Historically, around 90% wells have been completed with IGP completion and are producing sand free for the last 20-30 years. This paper describes on the first slim (3\") open hole standalone screen (OHSAS) completion application and performance which can be utilized for replication in future infill wells.\u0000 Around 10% remaining wells have been completed with OHSAS completion across highly deviated wells in H and I sands in T field. The screens have been designed based on d10 sand particle size and sand retention test (SRT) and typically installed in 8 ½\" open hole. The drill-in fluid (DIF) has been properly designed to create temporary filter cake across the wellbore and then it is designed to break by either lift-off pressure or by usage of mud cake breaker depending upon the type of DIF system.\u0000 The OHSAS wells are producing good with sand free production since last seven to fourteen years. The OHSAS performances for all wells in T field have been investigated. The investigation has provided suggestions for further improvement in future projects. Based on the investigation, OHSAS completions in T field has good OHSAS design and production performance, though further improvement can be done in its execution for future projects like monitoring total soluble clays using Methylene Blue Test (MBT) during drilling reservoir sections, maintaining its solubility more than 70% all throughout, use of proper mud cake breaker, etc. This paper explains details on the outcome of the investigation and recommendations, and data requirement to assess successful OHSAS completions with the help of tables and charts. The applicability of OHSAS has been re-studied in future infill wells and have been included in the next field development plans.\u0000 This paper presents on the OHSAS design, execution and performance, best practices, reviews and suggestions for further improvement in future infill wells, then its applicability and replication in future projects.","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"94 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125398219","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":"Temporary Zonal Protection Success Using HEC Based Gel Allows the Use of High Strength Conformance Sealant as a Barrier for Cross-Flow Behind Casing Remediation and Water Shut off Treatment: Offshore Vietnam","authors":"Tuanangkoon Daohmareeyor, T. Nguyen, Reawat Wattanasuwankorn","doi":"10.2118/209908-ms","DOIUrl":"https://doi.org/10.2118/209908-ms","url":null,"abstract":"\u0000 Unwanted water production in mature wells is one of the main issues for oil and gas operators worldwide, causing several economic issues related to hydrocarbon production. Furthermore, in this scenario, the swell packer installed between the water and oil-producing intervals had failed, resulting in communication behind the casing. This created difficulties when trying to shut off water-producing intervals without impacting the oil-producing intervals.\u0000 This paper will discuss and outline the shut-off technique, factors considered as part of the job design, the sealant and temporary gel protection design with lab testing, and describe the job implementation of this case study.\u0000 Hydroxyethyl Cellulose (HEC) based gel was selected as the temporary zonal protection in the lower, low-pressure reservoir interval, while the sealant gel was designed to shut off the higher pressure upper reservoir interval. The use of Coiled Tubing (CT) allowed the fluids to be placed precisely at the desired interval before applying squeeze pressure to force the treatment fluid further into the near-wellbore region, increasing the overall chance of success. Several critical concerns were outlined, such as the inability of the HEC based gel to be able to set and self-degrade in the required time, excessive gel penetration into the formation leading to formation damage, difficulties for wellbore clean up after the treatment, and the uncertainty of the leaking swell packers capability of sealing between the intervals behind the casing. Multiple lab tests were also designed to verify the suitability of the temporary gel and thixotropic particulate gel systems in achieving overall operational success.\u0000 The zonal protection fluid treatment was successfully mixed and pumped according to plan to create the temporary zonal protection (barrier). Verification was achieved by tagging the top of the barrier and observing the pressure change in the real-time downhole gauge. The thixotropic particulate gel sealant treatment was then tailed in and squeezed into the upper interval to shut off the zone and create an annular barrier behind the casing to isolate different intervals. Once the fluid treatment stage was complete, all the remaining gel in the tubing was successfully removed using CT with a rotating jet nozzle. An organic acid blend was then squeezed across the lower intervals to accelerate gel degradation time, followed by the flow back operation to test the treatment effectiveness. Final flow test results showed a reduction in water cut from 82% to 64% and an oil production increase of 400 bopd to 550 bopd.\u0000 A significant challenge was to create the temporary zonal protection of the lower oil-producing intervals and shut off the water-producing interval above while creating an annular barrier behind the casing within the same well. This achievement of a successful operation with detailed fluid design, placement techniques, risk mitigation plans, and good collaboration betwe","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133140341","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":"Empowering Collaboration and Refining Acumen with Rig Acceptance Workflow Digitalization","authors":"M. M. H. Meor Hashim, L. Norhashimi, N. Norazman, M. Arriffin","doi":"10.2118/209859-ms","DOIUrl":"https://doi.org/10.2118/209859-ms","url":null,"abstract":"\u0000 Current rig acceptance workflow practiced by many operators globally has been inefficient and this gap has been apparent for years. Redundancy, accountability issues and resource wastages can be quite complicated. In a typical workflow, the issues encountered include lack of accountability by inspectors toward item closure, inability to generate snapshots of current status, limited access, and an unfit sharing process. Report formats are not standardized across different disciplines hence the experience is not seamless as there is no one-stop center to view aviation, marine, and HSE inspection items. The digitalization of rig acceptance workflow can help to overcome these pain points by having a single platform to allow multidiscipline parties to keep tabs on rig activation status and updates throughout company-wide operations globally during the rig acceptance process. This initiative introduces a much leaner and more seamless method of conducting rig acceptance. Migrating the manual paper-based workflow to a web-based one-stop center for all things related to rig acceptance (i.e., marine, rig, HSE, and aviation) is the main strategy. It grants the ability for inspectors and designated personnel to insert comments for each finding as well as the ability for inspectors to assign and edit severity levels for each finding. The single platform approach allows the possibility to link up the other checklist and findings on the same system and immediately reduce the redundancy of certain items that is similar to other checklists, which can be streamlined online. Therefore, implementation of this Digital Rig Acceptance Workflow (DRAW) solution can produce a user-friendly online platform to allow inspectors, project teams, management, and rig equipment subject matter experts to access the system anywhere, anytime. DRAW allows status updates and clarifications to be communicated via a single platform. It utilizes data input to produce actionable insights hence generating direct business value via improving process cycle efficiency in a project's well life cycle.","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"6 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122169792","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 Inside Fiberglass Casing, Wear Prediction and Management in Geothermal Wells","authors":"Florian Aichinger, M.-H. Beddelem, G. Germain, Louis Hirsinger, L. Gerbaud, R. Studer","doi":"10.2118/209848-ms","DOIUrl":"https://doi.org/10.2118/209848-ms","url":null,"abstract":"\u0000 \u0000 \u0000 Due to corrosive fluids being expected in the geothermal wells planned for the Champigny (Paris) district heating, fiberglass casing was used. It was deemed beneficial, if drilling operations could be performed with an exposed fiberglass casing, despite high expected wear.\u0000 This paper will lay out how a feasible strategy was planned, utilizing advanced wear prediction techniques for drilling inside fiberglass casing.\u0000 The study was conducted by CFG (compagnie Française de Géothermie) and funded by ADEME (Agence de la transition écologique)\u0000 \u0000 \u0000 \u0000 To achieve an accurate wear prediction three parameters are required: (1) Trajectory and actual tortuosity (2) Wear factors (3) Operations (number of rotations and distance slided).\u0000 Tortuosity was calibrated on offset wells (Aichinger, 2021) and expected operations were covered in scenario analyses.\u0000 Wear factors were determined using field calibration and laboratory testing. The field calibration was performed on three offset wells using an internal diameter interpretation method in which the wear is measured against the most probable elliptical casing shape and herby allowing wear measurement avoiding bias error. (Aichinger, 2016) The laboratory tests were conducted in Mines ParisTech / Armines including different fiberglass types, protectors, sideforce amplitude, rotation speed and lubricant.\u0000 Based on the derived parameters various drilling scenarios and the associated wear levels were simulated to decide on a drilling strategy.\u0000 \u0000 \u0000 \u0000 The main results are:\u0000 The main conclusions are:\u0000 \u0000 \u0000 \u0000 This paper should provide help to Engineers who plan to perform drilling operations inside fiberglass casing, mainly by providing Wear Factors, but also general guidelines on wear prediction and mitigation techniques.\u0000","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"570 ","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134545479","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 Novel Approach to Analyze Fracture Properties Utilizing Advanced Mud Logging","authors":"Ammar Qatari, Khalid Qubaisi, Steve Dsouza, C. Magnier","doi":"10.2118/209834-ms","DOIUrl":"https://doi.org/10.2118/209834-ms","url":null,"abstract":"\u0000 Mud logging, in essence, is a wellsite operation that investigates, records, and analyzes measurements obtained from the circulating drilling fluid that results in the measurement of cuttings and gas. It plays a vital role in the identification of downhole geological conditions, such as hydrocarbon presence and stratigraphy along with monitoring drilling conditions, to ensure safety of operations and improve efficiency. The objective of this paper is to utilize advanced mud logging analysis characteristics to establish a workflow to potentially identify fractures along an interval. Helium is used as the correlation parameter to potentially indicate fractures along the intended formation. Advanced mud logging provides a quantitative hydrocarbon measurement from the drilling mud rather than the qualitative measurements that regular mudlogging provides. Helium is one of the major components that advanced mudlogging provides and acts as an indicator of permeability in a formation. The process starts with a novel method to utilize helium to be a correlator of fractures within a formation in terms of identification and measurements along with tracking the fracture with time. The combination between current formation imaging procedures and helium readings from mud logs is proven to be a key potential indicator to establish a fracture identification pattern.\u0000 The utility of the correlated helium readings from mud logging and fractures from formation image logs is a major breakthrough into identifying formation fracture features. Tracking changes of such features in which mud logging readings are used directly as potential indicators of fractures in an anticipated well. Loss of circulation prediction and LCM designs are enhanced directly by this extra knowledge.","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"85 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122072436","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":"Reservoir Compaction and Surface Subsidence Assessment to Optimize Field Development Planning in Offshore Malay Basin, Malaysia","authors":"Priveen Raj Santha Moorthy, A. Chatterjee, A. Younessi, Amitava Ghosh","doi":"10.2118/209895-ms","DOIUrl":"https://doi.org/10.2118/209895-ms","url":null,"abstract":"\u0000 A geomechanical model calibrated to field data can be used to analyse the potentially severe impact of reservoir compaction on production. However, field data acquisition programmes can be expensive, and optimal reservoir monitoring design necessitates an understanding of reservoir dynamics. Forward geomechanical models can help establishing the appropriate field data gathering approach while reducing expenses and maximising value for model calibration. Significant reservoir compaction and surface subsidence have potential risks for fault reactivation, integrity of wells and surface facilities. This paper presents an integrated approach and workflow that combines geomechanically derived data, reservoir geometry and production data to predict reservoir compaction and surface subsidence throughout the life of the field. The results provide an essential understanding on the dynamics of production induced changes in effective stresses and formation mechanical properties and their impacts on the field development planning, risks mitigation and provision of contingencies for well construction and downhole and surface field monitoring requirements.","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131879913","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 Fracture Propagation Simulation with the Integration of Fully-Coupled Geomechanical and DFN Modeling","authors":"Wei Li, Yangyi Xing, Haijie Zhang, Tongtong Luo, Wenhong Li, Jinpeng He, Xingning Huang, Thanapol Singjaroen, Piyanuch Kieduppatum","doi":"10.2118/209925-ms","DOIUrl":"https://doi.org/10.2118/209925-ms","url":null,"abstract":"\u0000 Shale gas reservoirs are characterized in low gas abundance, poor permeability, lower natural productivity than the lower limit of industrial oil flow, and rapid formation energy decline. At present, the technology of horizontal well drilling and staged hydraulic fracturing is widely used for the exploitation of such low-porosity and low-permeability reservoirs. The long well section of the horizontal well in the reservoir and the hydraulic fractures formed by fracturing act as the \"underground expressway\" for the deep gas in the reservoir to flow toward the wellbore. Their combination can greatly increase the production performance of the oil and gas resources in the reservoir. Staged multi-cluster fracturing in horizontal wells is the key technology to achieve the profitable shale gas production. The results of on-site downhole perforation imaging and distributed optical fiber temperature and acoustic monitoring show that there are obvious non-uniform liquid inflow and expansion phenomena in each cluster of fractures during the fracturing process. Relevant research results also show that factors such as the heterogeneity of the reservoir and the stress interference caused by the propagation of multiple fractures are the main causes of the non-uniform propagation of hydraulic fractures. Therefore, it is accessible to simulate the complex balanced expansion of each cluster of fractures in the fracturing section to improve the coverage of hydraulic fractures in the horizontal well section with numerical simulation methods based on the basic theory of elasticity and fracture mechanics, to reveal how the above engineering geological factors influence and control the fracture propagation. The results of the simulation of the fracturing treatment section of the deep shale gas horizontal well by the fracture propagation model are consistent with the micro-seismic monitoring results,which has obvious significance for accelerating the exploitation of difficult-to-exploit resources and guaranteeing the supply of gas resources.","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131992713","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}