Day 1 Mon, September 30, 2019最新文献

{"title":"Novel 3D Fluid Displacement Simulations Improve Cement Job Design and Planning in the Gulf of Mexico","authors":"M. Bogaerts, J. Cardozo, N. Flamant, David Giam, V. Villar, J. Lehr","doi":"10.2118/196077-ms","DOIUrl":"https://doi.org/10.2118/196077-ms","url":null,"abstract":"A key to achieving zonal isolation is the complete removal of drilling mud from the annular space between casing and formation and the replacement of the mud by an appropriately designed cement slurry. Although fluid displacement simulators have been available in the industry since the 1990s, a new-generation mud removal simulator has been introduced that provides new levels of details and accuracy. The simulator can be used for all types of wells, but it especially brings value to complex wells such as those found in deepwater Gulf of Mexico.\u0000 The new fluid displacement simulator comprises a stiff-string centralization model that accurately predicts the casing standoff in a 3D wellbore. It accounts for fluid mixing inside the drillpipe and casing while the fluid travels down the wellbore and includes a high-resolution annular displacement simulator that accounts for the 3D wellbore shape and solves for azimuthal and axial flows. Thanks to these three new features, the simulator generates highly accurate and reliable results with which the cement job design can be optimized, leading to a higher probability of meeting job objectives and achieving zonal isolation.\u0000 The new generation simulator was used to design and optimize cement jobs in the Gulf of Mexico with strict cement job objectives. The results of the simulator were compared to actual results of post-job wireline cement evaluations logs. The paper includes several case studies of deepwater and shallow water cement jobs in various complex wellbore configurations. Actual cement job data were used to rerun the simulator, and the results were compared with both the prejob cement design and the post-job evaluation logs. The comparison shows that the wireline evaluation results match the fluid displacement simulations very closely when using the stiff-string centralization model in combination with the new fluid displacement simulator, therefore confirming the accuracy of the model.\u0000 Using the new stiff-string casing centralization and 3D fluid displacement simulator throughout the early planning and design of the cement job allows for an improved cement job design. The simulations highlight possible challenges early in the planning of the cement job so that any required changes or contingencies can be prepared ahead of time, thus resulting in a cement job design that meets the planned objectives.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"6 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127853522","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":"Metal Expandable Annular Sealing Systems for High Pressure Open Hole Zonal Isolation and Stimulation","authors":"Yosafat Esquitin, B. Schwanitz, G. Moreno, Natalia Avella, O. Henao","doi":"10.2118/196227-ms","DOIUrl":"https://doi.org/10.2118/196227-ms","url":null,"abstract":"\u0000 Metal expandable annular sealing systems were used in a 4 ½\" completion as an effective high-pressure isolation method inside 6\" open hole mudstone formation in the Foothills Basin of Colombia. Effective isolation proved to be historically difficult to achieve.\u0000 The operator was approached with a solid metal expandable sealing system with rotation capabilities as an annular barrier for a preferred cementless completion. The sealing system needed to be assembled on a full-bore liner able to deliver robust deployment with a high-pressure seal in a worse case washed-out scenario. The deployment of the system consisted of one annular barrier placed above and one annular barrier placed below the mudstone zone.\u0000 Following careful job planning with the operator, the rotationally capable completion was deployed without any incidents. To achieve pressure integrity to set the metal expandable annular barriers, a ball seat sealing system was incorporated to allow the system to be closed and the annular barriers to be set.\u0000 After putting the well onto the pipeline, the client recorded a 52% increase in their expected produc-tion from previous wells. Successful results were accomplished as effective isolation was achieved and enhanced production was obtained because of the effective stimulation. This paper overviews the appli-cation, design, implementation and results of the use of new metal annular sealing systems in a 4 ½\" completion as an effective high-pressure isolation method inside a 6\" open hole, drilled in fractured sandstone and mudstone formations.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"26 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123495802","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":"Co-Development of Multiple Targets in Permian Unconventional Reservoirs","authors":"Richard Cao, Chaohui Chen, A. Girardi, Ruijian Li, N. Chowdhury","doi":"10.2118/195910-ms","DOIUrl":"https://doi.org/10.2118/195910-ms","url":null,"abstract":"\u0000 Optimum co-development layout of multiple targets for unconventional reservoirs is extremely challenging due to complex 3-dimentional well interactions, stochastic well performance, complex fracture geometry, dynamic SRV/DRV evolution, heterogeneous rock properties, various operating conditions, and different economic drivers. In this study, an integrated workflow is developed and applied for co-development of multiple targets in Permian unconventional reservoirs.\u0000 In this workflow, the field pilot and trial measurements, Microseismic, geochemistry measurement, data analytics, detailed geomechanical and reservoir modeling, stochastic multiple history matching and forecast, all combined to quantify the horizontal and vertical interference factors and obtain production profiles for different co-development designs. The stochastic behavior of the well performance is explored from three different aspects: static rock properties, dynamic fracturing, and production. The SRV/DRV evolution are presented as the probability distribution function of half fracture length from Microseismic data and effective drainage half-length from stochastic modeling.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"86 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124956177","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 Robot for Removing Hydrate and Paraffin Plugs in Offshore Flexible Lines – Development and Experimental Trials","authors":"H. Santos, E. Perondi, A. V. Wentz, Anselmo Silva, D. Barone, E. Basso, N. R. S. D. Reis, M. Galassi, H. Pinto, B. Castro, André Ferreira, Lincoln Homero Thomé Ferreira, Igor Menes Ursine Krettli","doi":"10.2118/196015-ms","DOIUrl":"https://doi.org/10.2118/196015-ms","url":null,"abstract":"\u0000 Methane Hydrates and Paraffin Plugs in flexible lines are concerns in offshore production. They may stop wells for months, causing high financial losses. Sometimes, operators use depressurization techniques for hydrate removal. Other strategy is using coiled tubing or a similar unit in order to perform local heating or solvent injection. However, frequently these strategies are not successful. In those cases, a rig may perform the operation or the line may be lost.\u0000 This project developed a robotic system in order to perform a controlled local heating and remove obstructions. The robotic system developed is able to access the line from the production platform. It uses a self-locking system in order to exert high traction forces. An umbilical with neutral buoyancy and low friction coefficient allows significant drag reduction. It allows moving upwards and in pipes with a large number of curves. Coiled tubing and similar units cannot do that. Carbon fiber vessels and compact circuits give flexibility to move inside 4-inch flexible pipes. A novel theoretical model allows the cable traction calculation using an evolution of the Euler-Eytelwein equation.\u0000 Experimental tests validated this model using curved pipes, both empty and filled with a fluid and using different loads. Experimental tests also validated the external layer traction resistance. Furthermore, the carbon fiber vessels were pressure tested, indicating a collapse resistance of more than 550 bar (8.000 psi). In addition, exhaustive tests of the onboard electronics and of the surface control system guarantee the communication reliability.\u0000 Additionally, the 25 kN (5.6 kip) traction system was modeled theoretically considering the self-locking system, the contact with the wall and a diameter range. Four prototypes allowed to: a) compare hydraulic and electric drive systems, b) validate the self-locking mechanism up to its limit, c) analyze the hydraulic system for leg opening and translation and d) prove the traction capacity. Finally, a theoretical model for the local heating system was developed. The system experimental validation on a cooled environment demonstrated its capacity of increasing temperature. Furthermore, it allows the obstruction removal in a controlled manner, avoiding damage to the polymeric layer of the flexible line.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128597594","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":"Eliminating Guesswork in Downhole Diagnostics with Definitive Answers from Downhole X-ray Technology","authors":"Saad Hamid, Abdulrahman A. Almulhim, R. Achihai, M. Spannuth","doi":"10.2118/196061-ms","DOIUrl":"https://doi.org/10.2118/196061-ms","url":null,"abstract":"\u0000 When a restriction or non-conformity presents itself in a well, quickly and reliably diagnosing the nature of the anomaly can save diagnostic runs and help prevent similar cases elsewhere, reducing nonproductive time and operating costs. Downhole X-ray diagnostics provide this understanding quickly and reliably under diverse well conditions that limit the effectiveness of other downhole diagnostic techniques. X-ray diagnostics produce real-time, quantitative two-dimensional images and three-dimensional reconstructions of downhole objects and obstructions with high precision. We demonstrate this with a case study in which X-ray diagnostics accurately identified and quantitatively characterized an obstruction due to liner deformation.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"47 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129339202","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":"Risk-Based Audit as a Strategic Tool for Improving Accountability in PSC System","authors":"Hafidh Arifianto, I. S. Putra","doi":"10.2118/196068-ms","DOIUrl":"https://doi.org/10.2118/196068-ms","url":null,"abstract":"\u0000 Cost recovery is an integral part of Indonesian Production Sharing Contract (PSC). The mechanism function as an incentive to attract investment in oil and gas exploration and production. The separation of function in PSC between the government and the contractor leads an information asymmetry over cost recovery. This issue makes the cost recovery calculation vulnerable to manipulation. In the context of the agency problem, the audit on cost recovery is deemed crucial as the government procedure to secure its share from inappropriate reimbursed cost.\u0000 The paper presents the challenge of traditional cost recovery audit, and a proposal to implement a Risk-Based Audit (RBA) approach as a strategic monitoring tool over cost recovery. The RBA provides an efficient and effective audit practice to maintain audit quality. The paper also adds to the literature on the government practice in addressing agency problem in PSC's cost reimbursement system based on a case study in Indonesian PSC environment.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"72 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127274802","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":"Validation of the Utility of the Contrast-Agent-Assisted Electromagnetic Tomography Method for Precise Imaging of a Hydraulically Induced Fracture Network","authors":"Mohsen Ahmadian, D. LaBrecque, Q. Liu, A. Kleinhammes, P. Doyle, Yuan Fang, G PaineJeffrey, Costard Lucie","doi":"10.2118/196140-ms","DOIUrl":"https://doi.org/10.2118/196140-ms","url":null,"abstract":"\u0000 Characterizing hydraulically induced fractures—height, length, orientation, and shape—is key to understanding reservoir performance. Our previous work has focused on the comparison of the state-of-the-art geophysical techniques currently used in hydraulic fracture imaging (microseismicity, tracer, tiltmeter, and distributed acoustic and temperature sensors) to perform a comprehensive set of electromagnetically active proppant (EAP)–assisted tomography methods (LaBrecque et al., 2016; Ahmadian et al., 2018). In our latest study, we conducted a field pilot at The University of Texas at Austin Bureau of Economic Geology's Devine Test Site, located approximately 50 miles southwest of San Antonio, Texas. Following hydraulic fracturing with EAP, we detected a measurable electromagnetic (EM) fracture anomaly at a depth of 175 ft (~53 m) by use of a set of four PVC-cased wells equipped with electrode arrays for single hole, hole-to-surface, and cross-hole electrical resistivity tomography. Because of relatively low overburden pressure, and as designed, fractures grew horizontally and appear nonaxisymmetric about the center injection well (fracture image looks like a human foot). This design allowed us to verify our results with drilling and logging of eight vertical wells. In addition, we cored two wells, and these samples further corroborated the presence of EAP proppants at the predicted depth. Together, these results conclusively corroborate the accuracy of our EM inversion models to within 5 ft of the physical edge of the EAP-filled fracture anomaly. We are currently using results from our ongoing geophysical surveys to refine and verify the efficiency of forward and inverse EM modeling codes for open-borehole and through steel casing scenarios. This paper describes the ground-truth validation of our model predictions, as well as the future direction of our research.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131690153","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":"Automated Influx and Loss Detection System Based on Advanced Mud Flow Modeling","authors":"Aurore Lafond, F. Leblay, Ghislain Roguin, M. Ringer","doi":"10.2118/195835-ms","DOIUrl":"https://doi.org/10.2118/195835-ms","url":null,"abstract":"\u0000 Maintaining well control is one of the most important considerations of any drilling operation, and early detection of formation fluid influx or mud losses is vital to safe drilling.\u0000 Today's gain and loss detection tends to trigger too many false alarms; major improvements in reliability (few to no false alarms) and reactivity (no missed events) are needed without being user dependent. The new developed system optimizes both accuracy and efficiency. This system maintains a false alarm rate lower than current system, while detecting influxes or losses as low as 40 gal. It applies also to a wide variety of configuration: deepwater, managed pressure drilling, land rig operations, etc. This performance is achieved through a new flow-modeling processes combined with automated settings, real-time quality control and guided, intuitive software interfaces. From a purely user-dependent system, the new kick detection software is now based on automated processes, ensuring repeatable and optimal detection performances while minimizing risks of human error. The detection of abnormal flow conditions in the well relies on the comparison of predicted and measured flow at the exit of the well. The improvements of the flow modeling, such as new, calibrated pump-efficiency models based on the isothermal modeling of the pumps, increase the robustness and the reactivity of the detection system. The presented case studies allow quantifying improvements of the kick detection performance between the existing system and the new version, benchmarking both the influx-detection reactivity and the system reliability. Kick detection charts used in the study represent a new way of illustrating detection performances.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"60 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125378974","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":"Lessons Learned from Casing-Casing Annulus Repair Utilizing Rigless Operation Approach in Offshore Oil Field","authors":"A. Al-Dhafeeri, Sultan A. Al-Aklubi, Shebl Fouad Abo Zkery","doi":"10.2118/195873-ms","DOIUrl":"https://doi.org/10.2118/195873-ms","url":null,"abstract":"\u0000 Several aged oil wells in offshore oil field are drilled in a conventional method. These wells are subjected to Casing-Casing Annulus (CCA) problems that might appear during the production operation and/or the shutdown phases. A continuous monitoring is performed to avoid issues related to well integrity and safety. The expected source of Casing-Casing Annulus (CCA) problem is mainly due to poor primarily cementing placement into the outer-casing strings especially across shallow aquifers formations. Due to long shutdown period on subject wells, these wells are encountered with high rate of CCA phenomena among other wells. An immediate mitigation action is required to resolve the issues by applying rig workover operation which is considered highly cost approach with low success rate. The rig workover operation results might lead to suspension or abandonment of these wells. The impact will affect the production target and the oil recovery around the area.\u0000 A new methodology approach was selected using chemical sealant recipes as a rigless operation to repair CCA problem with cost-effective and safe manner for first time in offshore filed. Based on the wellhead and annuli survey, the bleed down and build up tests were conducted and followed by close monitoring on suspected wells, which revealed sustained casing pressures and fluid return at the surface. Several fluid samples were collected and analyzed in the lab. Based on the findings, the procedures and the proper design were conducted to inject the chemical sealant into connected cement channels behind casing strings. Curing time and injection rate with required volumes of chemicals were considered based on the pressure responses and chemical performance.\u0000 The results from the rigless operation job utilizing the new approach showed wide-ranging success rates based on well by well cases and conditions such as 1) Age of the well, 2) Sustained pressure observed at the surface, 3) Injectivity rates, 4) Chemical additives volume and 5) Downhole conditions (pressure / temperature).\u0000 The new technique added a great value on restoring the well integrity and saving the rig operation cost. In addition, the approach contributed to achieve maximum sustainable production target through ensuring the well operability and reducing the production down time. Challenges, methodology, work schedule, risk assessment, lessons learned and findings have been covered in this paper.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"17 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126383875","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":"Deep Learning for Well Data History Analysis","authors":"Yuanjun Li, R.-H. Sun, R. Horne","doi":"10.2118/196011-ms","DOIUrl":"https://doi.org/10.2118/196011-ms","url":null,"abstract":"\u0000 The rapid development of machine learning algorithms and the massive accumulation of well data from continuous monitoring has enabled new applications in the oil and gas industries. Data gathered from well sensors are a foundation of the oilfield digitization and data-driven analysis. Here, we describe a deep learning approach to predict the long-term well performance based on a moderate duration of well monitoring data.\u0000 In this study, we first developed the data processing procedures for oilfield time series data and determined the proper selection of data sampling frequency, parameter combinations and data structures for deep learning models. Then we explored how Deep Learning (DL) models can be employed for well data analysis and how can we combine physics and DL models. Recurrent Neural Network (RNN) is a type of sequential DL model, which can be utilized for time series data analysis. This approach preserves preceding information and yields current response with memory of prior well behavior. Two candidate RNN models were tried to determine how well they were able to improve the accuracy and stability of well performance estimates. These two methods are Gated Recurrent Unit (GRU) and Long Short Term Memory (LSTM). In addition, a novel combination of RNN with Convolutional Neural Networks (CNNs), Long- and Short-term Time-series network (LSTNet), was also investigated.\u0000 These various models were tested and compared based on the public production datasets from Volve Field. Both GRU and LSTM achieved higher accuracy in performance prediction compared to the simple RNN. In the case of frequent well shut-in and opening, the failure in capturing fast pressure responses and the extreme fluctuations with the simple RNN ultimately leads to high error. In contrast, LSTNet is more stable to frequent or significant well variations. With advanced deep learning structures, engineers can interpret long-term reservoir performance information from responses estimated by deep learning models, instead of performing costly well tests or shut-ins.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122164424","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}