Day 3 Fri, March 03, 2023最新文献

{"title":"A Hybrid Physics and Active Learning Model For CFD-Based Pipeline CO2 and O2 Corrosion Prediction","authors":"Huihui Yang, Ligang Lu, Kuochen Tsai, Mohamed Sidahmed","doi":"10.2523/iptc-23049-ea","DOIUrl":"https://doi.org/10.2523/iptc-23049-ea","url":null,"abstract":"\u0000 Pipeline corrosion induced from CO2 or O2 is a serious and costly hazard for oil/gas industry. CO2 and O2 are different complex corrosion processes. We developed an innovative hybrid model that combines both the first principal physics and advanced machine learning (ML) method to build a single model that can predict multiple corrosion mechanisms involving CO2 andO2. It can significantly speed up corrosion analyses in complex geometry using computational fluid dynamics (CFD). The ML prediction output was used to account for the local effects of mass transfer limitations, which requires only four variables: average inlet_velocity, pipe_ID, pipe_bend_angle and the ratio of pipe_bend_radius and pipe_ID instead of the 7 variables including CO2 partial pressure, pH value and temperature. The last three variables were found to be almost independent on the local flow variables because CFD solutions were only obtained at the macroscale level while the microscale surface variable values are solved using mass transfer limitation correlations. This new approach greatly lowered the number of CFD simulations needed to generate data for machine learning models. The hybrid model is about 106 times faster than the CFD simulation with acceptable accuracies.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"1 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":"129756234","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":"Optimised Tripping and Drilling Performance Through Drilling Control System Automation to Control Axial Velocity","authors":"R. Bacon","doi":"10.2523/iptc-22969-ms","DOIUrl":"https://doi.org/10.2523/iptc-22969-ms","url":null,"abstract":"\u0000 \u0000 \u0000 The purpose of this paper is to document an ongoing project called \"Dual - velocity tubular running\" which is being used to optimize the drill-string and casing running speeds, with the view to trip as efficiently and quickly as the rig and geo pressure limitations allow but doing so in a safe manner that prevents nonproductive time, both visible and invisible, and always retains the wells integrity and allows safe operations. Dual speed refers to the ability to target an initial speed to safely break the mud gels, and a second tripping speed permissible once those same gels are broken, and this is illustrated in Figure 1.\u0000 This ‘dual speed’ optimization approach can be achieved by a more advanced use of mud gel-break and rheology data and a new auto sequence for stepwise axial velocity control.\u0000 This project is a step change in targeting an autonomous and optimized drilling process, and the impressive results that can be achieved can be seen in figure 2 above.\u0000 As many authors have noted, such as Cayeux E., E. W. Dvergsnes, F. P. Iversen 2009 there are many factors that contribute to nonproductive time, which include Lost circulation, formation influx, pack-offs and other stuck pipe events which cause delays, problems, lost time, and generally increase risk, and cost of the well, during drilling operations. Each of these has the potential to escalate into serious problems that can result in undesirable technical sidetracks. Couple this with ever more complex wells, (whether they be long horizontal sections, multi-laterals, etc.), and ensuring operations are done safely and efficiently is paramount. Furthermore, the traditional metrics of time and cost, are now further modified by the requirements to reduce the carbon footprint of operations. Anything which allows the well operations to be completed more quickly reduces the carbon footprint of the operation. The solution and concept presented in this paper showcases a modelling approach which allows all these situations to be accurately modelled in a transient setting, to optimize tubular running speeds – be that drill pipe, casing, liners, expandable liners, sand screens or any tubular string run in hole, and then also compared and back modelled using all the available real time high frequency data. This coupled with an automated drilling control system has resulted in safe, record-breaking drilling achievements in the North Sea. The models allow updated safeguards to be applied to the drilling control system to maintain a downhole pressure within the acceptable limits of the open hole formations. It also automatically stops the movement of the drill string in case of abnormal hook loads or surface torques. Since automatic actions can be triggered in case of an unexpected situation, some standard procedures have been fully automated, including friction tests and back-reaming. In prior papers such as Cayeux E., B. Daireaux, E. W. Dvergsnes, 2010,\" Automation of Mud-Pump Management : Applica","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"1 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":"133938806","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 New Method to Calculate Loading Liquid Water of Gas Wells in Qinghai Oilfield","authors":"Hao Wang, Jing Du, Jun Chen, Guangqiang Cao, Nan Li, Jianjun Zhu, Min Jia, Xiaopeng Yang","doi":"10.2523/iptc-22730-ea","DOIUrl":"https://doi.org/10.2523/iptc-22730-ea","url":null,"abstract":"\u0000 Sebei Gas Field is located in the Qaidam Basin, China, and is an unconsolidated sandstone gas reservoir with edge and bottom water layers. This special characteristics is a great challenge for gas production. As liquid column in the wellbore with a height of 1000 meters will bring 100 times of atmospheric pressure to the bottom of the well. Once the pressure of water in the wellbore is higher than the bottom hole flow pressure, the gas well will face the risk of shutdown. Actually most of the wells in Sebei, which have produced for several years, are producing water and taking drainage measures to assist gas producing. However, the exact moment of liquid loading is hard to determine, therefore the following drainage measures, also known as deliquifications, are difficult to design and optimize. Accurately and timely judging the degree and the height of liquid loading in the wellbore is one of the prerequisites for rational deliquification design. In this paper, Dr. Cao's liquid loading calculating model is applied to compute liquid loading in Sebei gas wells. The model is verified to be strong while the water production is relatively low but bring more errors for high water production. To solve the problem, a machine learning method is used to optimized and modified Cao’s model by adding a dynamic correction coefficient.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"59 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":"130970083","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 Simulation Assessment for the Effect of Asphaltene Deposition on Waterflooding in B Oilfield","authors":"Chang-yong Li","doi":"10.2523/iptc-22974-ms","DOIUrl":"https://doi.org/10.2523/iptc-22974-ms","url":null,"abstract":"\u0000 Asphaltene deposition has been observed in some wells within low-pressure areas in B oilfield during depletion. It is therefore concerns about asphaltene precipitation in the reservoir casued by decreasing pressure are raised. In this study, the impact of asphaltene deposition on water flooding in B oilfield was assessed by reservoir simulation.\u0000 This work built a new simulation model and investigated five kinds of formation damage due to asphaltene precipitation, which are porosity loss, permeability impairment, wettability alteration, relative permeability and capillary pressure changes, and oil viscosity variation. The instantaneous porosity loss equals to the volume of compressed pore and deposited asphaltene per grid block volume. The permeability impairment is calculated considering rock compressibility, asphaltene deposition on rock surface and throat plugging by asphaltene. The wettability alteration, oil-water relative permeability and capillary pressure changes were investigated according to published laboratory experiments, Gibbs adsorption theory and the modified Corey type model. Moreover, the oil viscosity variation was calculated by using a linear function model.\u0000 The simulation results show that asphaltene deposition in the reservoir would easily cause well skin and reduce the productivity index. As a result of wettability alteration caused by asphaltene surface deposition, the predicted oilfield water cut increases more quickly than that of the model without considering asphaltene deposition. Besides, the oil recovery factor reduces significantly when the reservoir pressure maintenance level is far lower than the upper onset pressure. The preferred reservoir pressure in a specific oilfield should be optimized based on sensitivity simulation cases to obtain a high oil recovery factor and slow water cut increase. B oilfield is recommended to maintain reservoir pressure around 5000 psi.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"1 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":"131124614","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":"Data Driven Modelling to Predict Poisson's Ratio and Maximum Horizontal Stress","authors":"Mariam Shreif, S. Kalam, Shams Khan","doi":"10.2523/iptc-23064-ms","DOIUrl":"https://doi.org/10.2523/iptc-23064-ms","url":null,"abstract":"\u0000 During the design phase of oil and gas well drilling plans, predicting geomechanical parameters is an indispensable job. Accurate estimation of the Poisson's ratio and the maximum horizontal stress is essential where inaccurate estimation may result in wellbore instability and casing collapse increasing the drilling cost. Obtaining mechanical rock properties using mechanical tests on cores is expensive and time-consuming. Machine learning algorithms may be utilized to get a reliable estimate for Poisson's ratio and the maximum horizontal stress. This research aims to estimate the static Poisson's ratio and the maximum horizontal stress based on influencing factors from well-log input data through an Extreme gradient boosting algorithm (XGBoost). In addition, the XGBoost model was also compared with Random Forest.\u0000 A real data set comprised of 22,325 data points was collected from the literature representing influencing variables which are compressional wave velocity, share wave velocity, bulk density, and pore pressure. The data set was split into 70% for training, and 30% for testing the model. XGBoost and random forest were used for training and testing the model. Mean absolute percentage error (MAPE), root mean squared error (RMSE), and coefficient of determination (R2) were assessed in the error metrics to obtain the optimum model. XGBoost and random forest were implemented using the k-fold cross-validation method integrated with grid search.\u0000 The proposed XGBoost model shows an effective correlation between the geomechanical parameters (static Poisson's ratio and the maximum horizontal stress) with the input variables. The performance of the XGBoost model was found better than that of the random forest. The evaluation estimates more than 90% of R2 and approximately 4% of MAPE for the training and testing data.\u0000 The key contribution of this work is the proposal of an intelligent model that estimates the geomechanical parameters without the need for destructive mechanical core testing. A reliable XGBoost model to predict the static Poisson's ratio and the maximum horizontal stress will allow improved wellbore stability analysis which significantly introduces efficiency gains.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"194 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":"129421020","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":"Pioneer in Integrated Workflow for Deep Transient Testing (DTT) from Interpretation to Forecast","authors":"Watanapong Ratawessanun, K. Hamdan, D. Ling, S. Daungkaew, A. Gisolf, P. Millot, C. Cavalleri, Bei Gao","doi":"10.2523/iptc-22964-ms","DOIUrl":"https://doi.org/10.2523/iptc-22964-ms","url":null,"abstract":"\u0000 Mini-DST, as alternative to conventional DST, has been in the industry more than 30 years, and its economic value has showed the advantage over DST, however limited permeability-thickness and investigated radius is a bottle neck which in many cases has much uncertainty to support reservoir characterization. The recently developed Deep Transient Testing technology improved its performance over former mini-DST technology in terms of longer pumping time, larger produced volume, and greater investigation radius. This paper presents a study in a variety of environments and applications, demonstrating how formation testing is being planned, acquired, and used in new ways, including Deep Transient Testing (DTT). The comprehensive radial model approach based on DTT using integration of well logs, numerical simulation grid and pressure transient behavior is built for the first time.\u0000 To design an effective approach to generate a radially gridded single well predictive model, this workflow requires knowledge of well performance, petrophysics and reservoir simulation. This simulation workflow started with a petrophysical interpretation together with well surveys which serve as essential input data to build a single well predictive model. Rock typing using Heterogenous Rock Analysis (HRA) method resulted in a more detailed properties population along the vertical direction in tartan grid. Defining completions of the well and followed by conversion of tartan grid to radial grid was performed to accurately capture the pressure transient response near wellbore. The radial grid model was setup as a DTT model to forecast the pressure transient behavior of the reservoir incorporating the technology of a new intelligent wireline formation testing platform in the simulation inputs.\u0000 The outcome of this study produced multiple scenarios incorporating different reservoir tightness from low to high with known thickness. The reason is that as the formation gets tighter; it is more challenging to achieve radial flow and predict producibility. By having uncertainty study in place, we can understand the outcome of each scenario then provide quantitative data to make decision on DTT feasibility, inlet and flow manager selections based on simulation result. This methodology not only optimizes the operation planning and execution, but also estimates pressure drop and the time needed to be on stationary for operational risk mitigation, which are in place to help operators improve certainty in decision making.\u0000 The case study showed that the advanced 3D radial grid predictive model method addressed the advantage of Interval Pressure Transient Testing (IPTT) and DTT in accessing and evaluating reservoir connectivity, heterogeneity, and drainage radius. In this paper, we are the pioneer in this robust Intelligent FT integrated workflow globally, which was successfully implemented together with all wireline operations within planned time frame involved and delivered with excepti","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"29 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":"116433500","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 Automated Workflow of Simplified Representative Elementary Volume (SREV) Approach to Sand Prediction and Control Monitoring (SPCM) Using Web-Based Interfaces to Reference with Operation Efficiency Improvement in Zawtika Field, Myanmar","authors":"Supha-Kitti Dhadachaipathomphong, P. Sooksawat, P. Toprasert, C. Peerakham, Nattapong Lertrojanachusit, F. Nazir, Fengjuan Wang, Melani Pattinama, Jiajun Dai, Mohammad Taufiq Lihawa, C. Chaiyasart","doi":"10.2523/iptc-22989-ms","DOIUrl":"https://doi.org/10.2523/iptc-22989-ms","url":null,"abstract":"\u0000 The oil and gas industry has been plagued by formation sand production for decades because of negative impacts on wellbore stability and equipment, despite the fact that it has been demonstrated to be a highly effective technique to increase well productivity (Wang, J. et al., 2004). The consequent sanding problem of sand production has been conducted, wearing down production equipment and necessitating environmentally acceptable disposal criteria. The sand production from unconsolidated sand formations in shallow depth have been reported 10% to 40% sand cuts with 5% in heavy oil reservoir (Tremblay, et al., 1999) and averaged 40% in light oil reservoir (Papamichos, et al., 2001). The objective is to increase operation efficiency of sand monitoring and control by using a sand prediction model to estimate sand production per well based on current operating conditions, as well as to calculate sand operating envelope for each well to guide the production planning and management. Vardoulakis I. and et al (1996) were the first proposed the hydro-erosion model based on rigid porous media in 1996. The erosion models were extended to include the effect of the deformation of porous media in a consistent manner (Wan and Wang, 2002) and include a fully coupled reservoir-geomechanics model as representative elementary volume (REV) to account for the effects of multiphase flow and geomechanics in a consistent manner (Wang et al., 2004). Methodology was starting from data collection, conducted Simplified Representative Elementary Volume (SREV), Integrated Asset model of well, model calibration, monitoring, integration of well, facility for prediction of sand accumulation and wall thickness condition. In addition, a data driven was imbedded to integration as well as workflow automation and user surveillance dashboard in web-based interfaces. The calibration process has been proved the models results with greater than 90% accuracy of sand production. It was found that SREV and IAM approach to sand prediction and control monitoring (SPCM) successful gave an improvement in operations efficiency by reducing time spent on manual analysis and decision-making process through dashboards with predictive results.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"6 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":"121058076","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":"Carbon Storage Monitoring in Saline Aquifers Using CSEM Data","authors":"S. Amani","doi":"10.2523/iptc-22984-ea","DOIUrl":"https://doi.org/10.2523/iptc-22984-ea","url":null,"abstract":"\u0000 Finding economical non-seismic methods for safe and long-term underground Carbon storage monitoring is significant. Electromagnetic methods such as controlled source electromagnetic (CSEM) are among the top economical and powerful geophysical methods for this purpose to investigate more. However, the CSEM monitoring of Carbon storage can be affected by shallower conductive materials due to their strong electromagnetic wave attenuation. So, the processing of controlled source electromagnetic (CSEM) data is investigated for monitoring Carbon storage in marine saline aquifers. High attenuation of CSEM data in the high conductive media should be considered. For safe Carbon storage, the potential for leak detection is also checked here. The solution of Maxwell's equations in a goal-oriented adaptive finite element approach is used to decrease the computational cost. This modeling method is advantageous for nonlinear inversion because the parameters can be modified to reach a certain amount of accuracy. A Carbon storage reservoir in a saline aquifer modeled for testing the CSEM monitoring method. The results confirm the high potential of this method for demonstrating the areas of target Carbon storage, its leak, and its surrounding structures.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"208 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":"114653549","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":"Taking Petrophysics to New Horizons – Far Field Saturation and Lithology in Clastic Reservoirs","authors":"Ida Bagus Gede Hermawan Manuaba, R. Ghanim, E. Bikchandaev, A. Taher","doi":"10.2523/iptc-23034-ms","DOIUrl":"https://doi.org/10.2523/iptc-23034-ms","url":null,"abstract":"Conventional logging-while-drilling tools acquire measurements close to the wellbore. Recent development of deep and ultra-deep resistivity technology has enabled measurements more than 100 ft from the wellbore. Far-field petrophysics in simple carbonate lithology is possible since saturation is dependent on resistivity and porosity. Hence, combining deep and ultra-deep resistivity measurements with data from offset wells can provide reasonable saturation mapping. However, in clastics the evaluation is more complicated since resistivity is more dependent on lithology.\u0000 In most cases, the main challenge in carbonates is permeability identification. Far-field carbonate petrophysics can be derived from mapped resistivity utilizing deep or ultra-deep resistivity and offset logs. Evaluation of far-field petrophysics away from the wellbore in clastics is more complicated as it requires lithology identification to be incorporated into the petrophysical model. A workflow has been developed integrating near-wellbore measurements with ultra-deep resistivity and anisotropy derived from 3D inversion. The workflow provides a qualitative indication of the lithology, allowing saturation in porous sand to be derived based on inverted resistivity.\u0000 An innovative workflow has been developed based on the available data and combining multiple sources of data from near wellbore, offset logs to inverted resistivity data. 3D inversion plays a critical role in this workflow as it provides a lithology indication far away from the wellbore, differentiating between shale and sand. The identification of shale members at a distance also provides critical information for models of reservoir connectivity and potential barriers to water influx. The combination of far-field petrophysics with lithology gives better evaluation on a reservoir scale for critical decisions in terms of completion and reservoir performance.\u0000 The new workflow has been successfully tested on several wells and different reservoirs. The workflow has been used for far field petrophysics and saturation mapping based on real-time logging-while-drilling (LWD) data and offset data analysis combining shallow and deep measurements with the 3D inversion from ultra-deep resistivity. There are several benefits from this innovative workflow, including optimizing well placement, improving understanding of fluid distribution, and optimizing completions design and reservoir management strategies.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"83 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":"114731023","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":"Real-Time Rig Less Intervention with a Catenary Coiled Tubing System to Perforate the Long Horizontal Section of a Well, Offshore Brunei","authors":"A. Leong, Rudzaifi Adizamri Abd Rani, Y. Azizan, Khairul Yusoff, Syahiran Idris, Hong Chean Lim","doi":"10.2523/iptc-23046-ms","DOIUrl":"https://doi.org/10.2523/iptc-23046-ms","url":null,"abstract":"\u0000 A horizontal oil development well offshore Brunei had unwanted gas zones needing to be isolated and its oil zones reperforated. Limited deck space, riser length, long gun length, and a long horizontal section posed many challenges for executing the operation using conventional methods. To overcome these, a customized perforation and detonation gun system was used for efficient and safe deployment into a live well with Coiled Tubing (CT) to reach the target depth along with a Real-Time (RT) CT system, allowing more accurate depth correlation for the plug setting and perforation.\u0000 A Solution to the limited deck space was developed using an integrated RT catenary CT unit, pumping, and flowback package. This setup allows most of the equipment to remain on the vessel while transferring only minimal items to the platform and keeping the capability of pumping and safely managing the flowback from a live well. An adjustment to the injector jacking frame was also made by designing an extension that would safely increase the height for the gun length to be deployed while remaining able to withstand any strong weather. Additionally, software simulations were performed to verify that the longest perforating gun could successfully be deployed in and out of the live well. Due to the long target interval needing perforated, a gun deployment system was selected to reduce tripping time instead of a more traditional section-by-section method. With a ninety-meter gun length deployment in a single trip for the longest interval, this deployment method saved twelves trips compared to the more conventional approach. Overall, considering three intervals to be perforated, this system eliminated a significant number of trips for the whole project. RT CT integrated with sophisticated and reliable sensors guaranteed depth accuracy during the correlation process. These sensors delivered RT Gamma Ray (GR), Casing Collar Locator (CCL), pressures, compression, tension, torque, inclination, and temperature, fulfilling the requirement of achieving accurate depth control and overall RT monitoring of downhole conditions. The electrical firing mechanism allowed a more straightforward and safer firing process than the alternative of circulating a ball.\u0000 This project marked the first successful operation to perforate more than two hundred and fifty meters of target horizontal interval with three long perforating guns. This approach saved twelve runs compared to the more conventional method, which also needs additional correlation runs. The customized solution demonstrates that critical operations in long horizontal wells in challenging offshore environments can be successfully and safely executed.","PeriodicalId":185347,"journal":{"name":"Day 3 Fri, March 03, 2023","volume":"36 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":"126943748","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}