Day 2 Mon, February 20, 2023最新文献

{"title":"Significant Impact of Non H-C Gases (NHG) on Reservoir Fluid of a Jurassic, HPHT and Tight Carbonate Discovery in North of Kuwait: A Case Study of a Sour and Critical Fluid Characteristics and Fluid Compartmentalization","authors":"S. Al-Dousari, Haifa Al-Bader, Ahmed M. Al-Otaibi, Sarah Al-Shuaib, Bahaskar Chakrabarti","doi":"10.2118/213472-ms","DOIUrl":"https://doi.org/10.2118/213472-ms","url":null,"abstract":"\u0000 The objective of this paper is to show the effect of non-HC gases NHG on critical fluid characterization of HPHT discovered deep Jurassic reservoir in north Kuwait in addition to Fluid characterization and compartmentalization with objective of assessing HC potential, well deliverability and reservoir fluid & rock characteristics.\u0000 Jurassic reservoirs in the state of Kuwait are deep and tight with High-Pressure and High-Temperature (HPHT) environment. The discovery well was drilled targeting the Marrat formation to prove hydrocarbon in this area. The well was successfully completed & tested and then a complete set of surface & subsurface data was acquired including production measurements and downhole P/T gauge data. The produced fluid was found highly sour and of critical-nature Therefore, a detailed fluid characterization process plus a fully-integrated G&G and Engineering analyses were performed to distinguish the fluid nature whether it is Volatile Oil or Gas Condensate and to prove reservoir and fluid compartmentalization using multiple PVT experiments and different analog wells from North Kuwait. Moreover, historical reservoir pressure and well performance for all the wells in this field were tracked and analyzed as t the discovered well was followed with an intensive appraisal campaign with variance in reservoir/fluids characteristics with objective of assessing HC potential for further Development plan to support achieving the strategic production targets. The four wells connected to one of Jurassic Facilities and ready for further development.\u0000 By integrating both reservoir and fluid analysis, The Northern part observed better reservoir quality and production performance, while reservoir layers are thinning toward the southern part of the structure with the appearance of organic content. The PVT depletion experiments along with compositional analysis and phase envelop all indicated reservoir fluid type is Volatile oil, where saturation pressure is sensitive to reservoir temperature and percentage of non-hydrocarbon gases H2S & CO2. As a result, the fluid found to be highly volatile oil with very high GOR. Fluid compartmentalization is also observed in this field between the three wells as the fluids were lighter towards the south, which will be confirmed after testing the fourth well that was initially drilled to prove the structure boundary/extension.\u0000 Tremendous exploration efforts and activities resulted in remarkable Jurassic light oil discovery with substantial addition of proven reserves and commercial production potential, which will definitely support achieving the strategic production targets. The exploratory and appraisal wells are currently connected to one of Kuwait's Jurassic facilities handling high concentrations of H2S. After the completion of exploration campaign and completing the fully-Integrated Engineering analyses the reservoir is ready to be transferred to the Hosting Field development.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122278742","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":"Viscometer Readings Prediction of Flat Rheology Drilling Fluids Using Adaptive Neuro-Fuzzy Inference System","authors":"Ahmed Abdelaal, S. Elkatatny, A. Ibrahim","doi":"10.2118/213648-ms","DOIUrl":"https://doi.org/10.2118/213648-ms","url":null,"abstract":"\u0000 Flat rheology drilling fluids are synthetic-based fluids designed to provide better drilling performance with flat rheological properties for deep water and/or cold environments. The detailed mud properties are mainly measured in laboratories and are often measured twice a day in the field. This prevents real-time mud performance optimization and negatively affects the decisions. If the real-time estimation of mud properties, which affects decision-making in time, is absent, the ROP may slow down, and serious drilling problems and severe economic losses may take place. Consequently, it is important to evaluate the mud properties while drilling to capture the dynamics of mudflow. Unlike other mud properties, mud density (MD) and Marsh funnel viscosity (MFV) are frequently measured every 15–20 minutes in the field. The objective of this study is to predict the viscometer readings at 300 and 600 RPM (R600 and R300) of the flat rheology mud in real-time using machine learning (ML) and then calculate the other rheological properties using the existing equations. The developed model using adaptive neuro-fuzzy inference system (ANFIS) predicted the viscometer readings with an acceptable accuracy. The maximum average absolute percentage error (AAPE) was less than 7 % and the correlation coefficient (R) was more than 0.96 for training, testing and validation.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128518167","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":"Investigation of Polymer Latex Effects on Cement Mechanical Properties for Improved Wellbore Integrity","authors":"A. Al-Yami, Hussam Al-Qahtani, Jaber Nizar, Majad Khan, Muhammad Nawaz Tahir, V. Wagle","doi":"10.2118/213747-ms","DOIUrl":"https://doi.org/10.2118/213747-ms","url":null,"abstract":"\u0000 Cement needs to be designed to prevent short-term and long-term gas migration scenarios. In the short term, the cement must prevent gas flow immediately following cement placement. In the long term, the cement must resist pressure and temperature cycling during drilling and production. Wells are subjected to substantial stresses from pressure and well testing, injection and stimulation treatments, thermal effects, production cycling, and changes in the surrounding formation over years. Due to these stresses, the cement sheath damage can occur during drilling, perforation and stimulation, and subsequent production. Polymer latex has been used to help reduce the fluid loss to minimize gas migration and aid in the mixing ability of cement slurries. However, there are some engineers who believe that polymer latex will improve cement mechanical properties.\u0000 The objective of this study is to evaluate the effect of polymer latex on cement mechanical properties after curing at elevated temperature and pressures. Experimental work in this study includes formulations at different polymer latex concentrations, densities measurements, rheology measurement, fluid loss testing, thickening time tests, curing for 30 days at elevated temperature and pressure, and finally mechanical properties measurements (Young's modulus, Poisson's ratio and compressive strength). The study shows that polymer latex will improve mechanical properties of cementing which will lead to improved wellbore integrity.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"99 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127257464","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":"Digital Twin of Degradable Fluid Loss Additive Supported by Advanced Slurry Flow Model","authors":"V. Isaev, A. M. Khan","doi":"10.2118/213301-ms","DOIUrl":"https://doi.org/10.2118/213301-ms","url":null,"abstract":"\u0000 This study is a part of larger scheme of reservoir strategy for use of degradable fluid loss additives. Components of this framework have been presented in two previous papers and this paper specifically describes the novel modeling approach. The hydraulic fracturing model accounts for the effect of fluid loss additive on fluid leakoff into the rock during the treatment. It is implemented with slurry flow model based on the lubrication theory. An empirical closure relation for Carter leakoff coefficient represents the effect of leaked fluid volume and the volume of fluid loss additive deposited in the filter cake. The numerical algorithm is based on the combined Eulerian-Lagrangian approach. A simulation example showing the effect of fluid loss additives on pad volume reduction and potential production performance enhancement is presented.\u0000 The presented approach is the first slurry flow model which allows to accurately simulate the benefits of fluid loss additive and aims to create a digital twin of these additives eliminating the need to conduct laboratory experiments and design scenarios, revamping the fracturing design strategy.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"38 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132584987","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":"An Overview of Advanced Subsurface and Surface Measurements for CCUS Project","authors":"Alia I Al-Zayani, Pramod D. Patil, Abdulaziz Alqasim, S. Kokal","doi":"10.2118/213510-ms","DOIUrl":"https://doi.org/10.2118/213510-ms","url":null,"abstract":"\u0000 Monitoring and surveillance (M&S) is one of the key requisites for assessing the effectiveness and success of any CCS/CCUS projects. It will help understand, track, monitor, and predict the Injectant plume migration, flow paths, and breakthrough times. The M&S helps in quantifying sequestered injected gas and any inadvertent leakage. It provides a good understanding of the remaining oil saturation (ROS) and its distribution in the reservoir.\u0000 A comprehensive and advanced monitoring and surveillance (M&S) program was developed and is currently being deployed to address CCS/CCUS project objectives. The advanced M&S plan incorporates conventional, advanced, and emerging novel technologies for wellbore and inter-well measurements. These include advanced time-lapse pulsed neutron, resistivity, diffusion logs, and bore-hole gravity measurements, cross-well geophysical measurements, water and gas tracers, geochemical, compositional and soil gas analyses, and 4D seismic and surface gravity measurements.\u0000 Results from monitoring and surveillance technologies provide a better understanding of the reservoir dynamics within the subject area. The results can be used to refine the reservoir simulation model and fine tune its parameters. This paper reviews some proven best practices and draws examples from ongoing projects and related novel technologies being deployed. It will then look at the new horizon for M&S technologies for CCS and CCUS.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133142504","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":"Unsupervised Machine Learning for Sweet-Spot Identification Within an Unconventional Carbonate Mudstone","authors":"Septriandi A. Chan, A. Amao, John T. Humphrey, Yaser Alzayer","doi":"10.2118/213353-ms","DOIUrl":"https://doi.org/10.2118/213353-ms","url":null,"abstract":"\u0000 Stratigraphic correlation in mudstone intervals is challenging as compared to coarser-grained sedimentary rocks because of the microscale heterogeneity and other constraints. Given critical mm- to cm-scale variability in mudstones, it is daunting to try to infer compositional variability from well logs and seismic data unless core data and laboratory analyses are available to calibrate the results. In this study, we propose a novel integrated approach combining sedimentological core description with geochemical data to establish chemofacies and chemostratigraphic zonation using a set of unsupervised statistical tools, i.e., Principal Component Analysis (PCA) and Hierarchical Clustering on Principal Components (HCPC).\u0000 These techniques can be applied to elemental data acquired using x-ray fluorescence measured from core or cuttings samples or spectroscopy logs to provide robust analysis for unconventional assessment regarding sweet-spot identification, sequence stratigraphic interpretations, and drilling and completion designs. Further, the identified zones can be used to characterize/correlate zones in nearby un-cored wells, with the data generated serving as an indispensable input for establishing a well-log data zonation using unsupervised machine learning algorithms.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"19 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129269819","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":"Magnetic Sensors for Navigation of Untethered Downhole Robots","authors":"H. Seren, M. Deffenbaugh, Mohamed Larbi Zeghlache, A. Bukhamseen","doi":"10.2118/213358-ms","DOIUrl":"https://doi.org/10.2118/213358-ms","url":null,"abstract":"\u0000 Following the 4IR revolution, automation of oil and gas operations became a prime target. Various efforts have been put forward to create autonomous downhole tools which can increase the time and cost efficiency while reducing health and safety hazards. Navigation of the autonomous tools remains as one of the high barriers preventing these technologies from becoming available. This manuscript presents three new solutions we developed for our untethered autonomous logging tool to overcome this barrier.\u0000 To increase the environmental self-awareness of downhole robots, we developed two technologies that will work together. The first technology is a low power miniaturized casing collar locator where a milimiter-size magnetometer chip and two 1-inch rod magnets are employed. The second technology is based on 1-D feature matching of residual magnetic fields generated by the steel casings. Here, two magnetometers are placed on the tool with a known separation along the direction of the motion. A correlation algorithm calculates the position and speed using the magnetic field logs.\u0000 The low power miniaturized casing collar locator is placed on a wireline tool for the proof of concept demonstration. The tool was run in a water filled test well with 1450 feet depth. Decentralizers were used to keep the tool close to the casing wall. Clear peaks were observed at regular intervals. The detection depths were compared to a casing collar log run by a logging service company and one to one match was observed. The 1-D magnetic feature matching technology is demonstrated first by collecting residual magnetic field data from the same test well with a wireline tool. The collected signal was shifted in space and noise is added to mimic the difference with a second magnetometer. The matching algorithm was used to successfully find the shift between the two signals in time along the full log. This helped to estimate the speed of the tool which is used to calculate the position. Using information from the presented technologies, along with the data from other environmental sensors such as pressure and temperature will provide precise location that were not available before. The certainty will be improved by employing a Kalman filter that will integrate the sensor inputs.\u0000 As in all autonomous vehicles, increasing the environmental self-awareness of autonomous downhole tools carries high importance for intelligent decision-making, successful and safe operation. Technologies fo surface applications, such as global positioning system, and radar may not be suitable for downhole environment. Therefore, new sensing technologies as we present here will accomplish these jobs for the robots operating below the surface.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"10 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115002002","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":"Intelligent Coiled Tubing Systems: Overview, Research Trends, and Challenges","authors":"Chengxi Li, Harpreet Singh, Pengyu Cheng, Xunjie Wang, Ge Hao, Qing Liu","doi":"10.2118/213762-ms","DOIUrl":"https://doi.org/10.2118/213762-ms","url":null,"abstract":"\u0000 In recent years, improving the efficiency of producing hydrocarbons from extended-reach horizontal wells has created a need to develop better well intervention, specifically coiled tubing (CT) solutions. However, because the conventional coiled tubing system only relies on surface data to monitor and predict downhole conditions, its application's effectiveness, accuracy, and efficiency still need to be improved. On the other hand, intelligent coiled tubing interventions use real-time downhole data to improve operational efficiency and performance. The objective of this paper is to present a detailed review of the fundamental principles and applications of intelligent coiled tubing systems and a discussion of the challenges and prospects of intelligent coiled tubing technology. Based on the different telemetry systems, the Intelligent Coiled Tubing technology can be categorized into three systems: Tube-Wire System, Fiber-Optic System, and Hybrid Electric-Optical Cable System. This paper will mainly focus on these three types of intelligent coiled tubing systems with a detailed review of the system functionalities, features, surface equipment, bottom hole assemblies, downhole sensors, and critical applications supported by case studies. A summary of the conventional coiled tubing equipment, tools, and applications is also included as technical background for the readers. The current technology status of the major operators is also summarized, representing the most advanced technology and service available on the market. In this study, we give a thorough overview of the Intelligent Coiled Tubing technology systems currently on the market and identify potential applications that intelligent coiled tubing can bring value to improve efficiency and performance. We also present several case studies of intelligent coiled tubing. Based on the case studies data, we summarize these critical applications and evaluate the values created using intelligent coil tubing systems. From the analysis, we find that the real-time monitoring, diagnosis, and decision-making functions of intelligent coiled tubing can efficiently solve operational problems in real-time, improve operational efficiency, increase tool life, and reduce downhole accidents while achieving increased production because of parameter optimization and correct decision-making. The paper introduces the working principle of intelligent coiled tubing technologies and case studies in various fields with different operational conditions. The proposed paper thus gives a clear and big picture of this topic from various aspects. We further extract and summarize the critical knowledge from the most recent case studies of intelligent coiled tubing technology. As a result, this paper will facilitate operators with less experience in intelligent coiled tubing technology to understand and apply this technique efficiently.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"32 11","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"113975054","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":"Enabling Reliable Stimulation of Multiple Perforated Intervals in a Thick Laminated Reservoir: Lessons Learnt in Successful Sequenced Fracturing Evaluation","authors":"A. Asif, A. M. Khan, Abdulaziz Alaqeel, R. Kayumov","doi":"10.2118/213261-ms","DOIUrl":"https://doi.org/10.2118/213261-ms","url":null,"abstract":"\u0000 Near-wellbore fracture diversion is a common means of achieving uniform stimulation in long wellbores through heterogeneous reservoirs. A novel sequenced fracturing technique using self-degradable, nondamaging, multimodal particulate pills was deployed for the first time in a clastic rock formation in the Middle East. Application of an advanced design and evaluation workflow to stimulate two perforated intervals in a single continuous pumping operation is presented.\u0000 Sequenced fracturing with two-step diversion was combined with channel fracturing to increase the chance of successful placement and reduce the inherent risk of screenout. Two proppant ramps were pumped, separated by a diverter pill composed of a multimodal particulate blend and fibers. The size distribution and volume of particles were optimized to create a low-permeability plug in the entry of the primary fracture. The pills were designed so that large particles would intercept the fracture entrance and smaller ones would reduce the permeability of the formed plug, while the fibers would help to maintain the plug integrity both during pumping and once it formed in the near wellbore region.\u0000 Diversion was confirmed by a pressure increase of 800 psi during the placement of the pill, followed by a new breakdown signature and a treating pressure increase of 500 psi at the same pumping rate. The diversion design was optimized based on the temperature log before fracturing to evaluate the preferential fracture geometry. The evaluation was conducted with a nonradioactive traceable proppant that was pumped in the second proppant ramp to assess the proppant placement using a neutron log. Consequently, a production log was conducted followed by pressure diagnostics. Since the diagnostic results indicated some ambiguity, for a way forward in the field development, the upper interval was refractured and showed high pressures and early treatment termination. The entire flowback timeline was compared, and the productivity index showed no change before and after refracturing. Therefore, multiple pressure diagnostics, post-fracturing flowback enhancement, and the overall intense evaluation verified proppant placement in both perforated intervals using the sequenced fracturing technique. The technique has the potential to save up to 10 days of completion time, which was calculated to yield approximately 40% time and cost savings.\u0000 This paper presents a complex stimulation treatment analysis that can be utilized to apply the lessons learnt in design and evaluating the success of diversion treatments to aid future treatments. This proven technology enhances efficiency and economics, especially in multistage fracturing, where the efficiency could be enhanced by three- to fivefold.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"424 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115234000","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":"Perforation Efficiency Estimation Through Soft Shutdown Results in Multi-Stage Slickwater Stimulated Wells","authors":"Halah Alghanim, Abdulrahman Alowaid, S. Baki, Nouf Alsulaiman","doi":"10.2118/213272-ms","DOIUrl":"https://doi.org/10.2118/213272-ms","url":null,"abstract":"\u0000 One of the key parameters in identifying the success of fracture placement is to determine the number of perforations contributing to creating fractures from each hydraulic fracturing stage. One of the popular methods of estimating perforation contribution and near-wellbore pressure frictional losses is by performing step-down tests (SDT). The only drawback of this methodology is that the rate has to be dropped in a step-wise fashion, which introduces operational constraints. At the area of the implementation, frac treatment designed rate is 92 barrel-per-minute (bpm) and is reduced to zero to shut-in the well in step-wise fashion. The objective of this paper is to exploit the opportunity of utilizing the common practice of soft shutdown (SSD), where rate is dropped to 60 (bpm) then to zero at the end of the stage frac job to act like a mini SDT as a practical alternative solution.\u0000 The proposed methodology entails conducting a tailored rate SDT on one well, and utilizing the shutdown period as a substitute to SDT on another well, specifically selected to be of the same conditions in terms of formation landing zone, stimulation treatment design and perforation count. A typical SDT is conducted by dropping the pump rate gradually in step-wise decrements. In this particular approach, two SDTs were performed within a single frac job, one at the beginning of the job before the introduction of proppant, and the other at the end after the flush period. Whereas in the SSD test approach, rate is dropped in only two steps at the end of the job and no time interval is specified. Pressure and rate are then selected as data points from each step, with instantaneous shut-in pressure (ISIP) considered as the final data point. It is important to keep as many variables fixed as possible in order to have the pressure response contributed by wellbore and perforation frictional components only. The selected data points are then plotted as pressure versus rate and matched with frictional losses and number of open perforations. The methodology capitalizes on the availability of SSD data, and evaluate its feasibility as a substitute to SDT.\u0000 By performing this type of analysis, an estimate of perforation efficiency from both methodologies was achieved. Although two different results were retrieved from the SDT obtained from the beginning and the end of the frac job, the one performed at the flush stage was the focus of this study as it mimics the most realistic setting of perforation efficiency post treatment. Although lower number of data points are obtained from the SSD approach, it did not obscure matching the calculated pressure to the selected pressure-rate data points. In fact, the results from the SSD indicated a variance of as low as 2% when compared to SDT results from a mirror stage. This small variation demonstrated the technical and practical feasibility of utilizing SSD as a strong substitute to SDT, promoting the effectiveness of this robust methodolog","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"67 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116608167","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}