Day 2 Tue, August 17, 2021最新文献

{"title":"Accelerated Development of Pressure Balanced HPHT Dissolvable Plugged Nozzle Assemblies Through the Nippon Foundation-DeepStar Joint Ocean Innovation R&D Program for Extended Reach Deepwater Wells, Within a Short Time of Project Launch","authors":"T. Roy, Daniel Markel, Christian Wilkinson, Yoshihiko Koyanagi, Chihiro Furusho, Hiroyuki Watanabe, Gustavo Grullon, H. Elshahawi, R. Shenoy, Indranil Roy","doi":"10.4043/30927-ms","DOIUrl":"https://doi.org/10.4043/30927-ms","url":null,"abstract":"\u0000 To meet and sustain the increasing energy needs of a growing world economy, exploration for oil and gas will be directed to increasingly extended reaches, complex profiles and hostile environments. Progress in harnessing high-pressure high-temperature (HPHT) sour fields (environments containing hydrogen sulphide gas or H2S) and reducing the cost of extracting and refining will be highly leveraged by political and macroeconomic considerations. Motivated to harness the complex tight carbonate reservoirs in offshore Arabian Gulf, a major National Oil Company (NOC) in UAE and its partners embarked on an extensive and ambitious project to produce oil and gas from offshore artificial islands. To capture the full economic benefits of this project, operators are expected to drill farther and farther into one of the world's longest deep-water reservoirs (wells with laterals lengths beyond 40,000 feet). It has also taken them a decade of innovative technology development to be able to successfully harness these challenging deep-water assets. Among the technologies developed, one of the essential tools, a dissolvable plugged nozzle assembly (DPNA) with its ability to withstand higher pressures encountered at larger depths, while maintaining its mechanical integrity for extended times in heavy brines, enabling longer sweeps, thus service deeper wells was needed by operators. Recognizing this grand challenge, we designed and developed a pressure balanced HPHT DPN (PB-HPHT DPN) with erosion resistant Ni alloy jointly developed with a major Japanese steel and Ni alloy producer and anion-insensitive nano-BMGC plug developed by us. The PB-HPHT DPN has the following groundbreaking properties: (i) It can sustain pressures of up to 5,500 psi differential pressure (ΔP) for 48 hours when pressurized from inner diameter (ID) to outer diameter (OD), and can subsequently breakthrough on 500 psi DP pressure reversal (OD to ID) within 14 days from the start of the operations; (ii) It can be deployed in environments encompassing up-to 43% Bromide or up-to 21% Chloride brines and reaching temperatures as high as 250° F. Additionally, verification and validation (V&V) is supported by flow testing combined with Computational Fluid Dynamics (CFD). The design of the PB HPHT-DPN allows a fluid flow of up-to 0.6 bpm across the nozzle without experiencing a differential pressure increase of >2400 psi in a 4 mm DPN. In summary, the PB-HPHT DPN is a revolutionary device that will allow operators to efficiently produce oil and gas in extremely hostile environments.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"15 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89688615","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":"Detecting Interesting and Anomalous Patterns In Multivariate Time-Series Data in an Offshore Platform Using Unsupervised Learning","authors":"Ilan Sousa Figueirêdo, T. Carvalho, Wenisten J. D. Silva, L. Guarieiro, E. G. S. Nascimento","doi":"10.4043/31297-ms","DOIUrl":"https://doi.org/10.4043/31297-ms","url":null,"abstract":"\u0000 Detection of anomalous events in practical operation of oil and gas (O&G) wells and lines can help to avoid production losses, environmental disasters, and human fatalities, besides decreasing maintenance costs. Supervised machine learning algorithms have been successful to detect, diagnose, and forecast anomalous events in O&G industry. Nevertheless, these algorithms need a large quantity of annotated dataset and labelling data in real world scenarios is typically unfeasible because of exhaustive work of experts. Therefore, as unsupervised machine learning does not require an annotated dataset, this paper intends to perform a comparative evaluation performance of unsupervised learning algorithms to support experts for anomaly detection and pattern recognition in multivariate time-series data. So, the goal is to allow experts to analyze a small set of patterns and label them, instead of analyzing large datasets. This paper used the public 3W database of three offshore naturally flowing wells. The experiment used real data of production of O&G from underground reservoirs with the following anomalous events: (i) spurious closure of Downhole Safety Valve (DHSV) and (ii) quick restriction in Production Choke (PCK). Six unsupervised machine learning algorithms were assessed: Cluster-based Algorithm for Anomaly Detection in Time Series Using Mahalanobis Distance (C-AMDATS), Luminol Bitmap, SAX-REPEAT, k-NN, Bootstrap, and Robust Random Cut Forest (RRCF). The comparison evaluation of unsupervised learning algorithms was performed using a set of metrics: accuracy (ACC), precision (PR), recall (REC), specificity (SP), F1-Score (F1), Area Under the Receiver Operating Characteristic Curve (AUC-ROC), and Area Under the Precision-Recall Curve (AUC-PRC). The experiments only used the data labels for assessment purposes. The results revealed that unsupervised learning successfully detected the patterns of interest in multivariate data without prior annotation, with emphasis on the C-AMDATS algorithm. Thus, unsupervised learning can leverage supervised models through the support given to data annotation.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"7 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75003053","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":"Selecting a Product for Wax Remediation: From Characterization of Field Wax Deposits to Improvement of Treatment Sustainability","authors":"J. I. Aguiar, Antonio A. Pontifes, J. Rogers, A. Mahmoudkhani","doi":"10.4043/30951-ms","DOIUrl":"https://doi.org/10.4043/30951-ms","url":null,"abstract":"\u0000 Wax deposition is one of the known challenges of flow assurance management in upstream oil production and operations demanding continuous improvements and the search for more effective prevention and remediation methods. At the same time, there are no universally agreed upon test methods to evaluate the efficiency and mechanisms related to the chemical treatments. The objective of this paper is to present and debate different methods to evaluate the effectiveness of batch treatments for remediation of wax deposits and compare commonly applied solvents with fluids containing biosurfactants. One of the presented methods is a new test methodology that simulates dynamic and quasi-static flow regimes in production tubing and pipelines, as benchmarked methods, showed that the chemical treatments with biosurfactants, besides being a greener, sustainable option, were more efficient at dispersing wax deposits than the traditional solvent treatments.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"8 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84756308","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":"On the Likelihood of Encountering Design Conditions During Heavy Transport - A Case Study of 56 Replicate Voyages From Korea to the Suez Canal","authors":"David P. Hodapp, Stephan den Breejen, Tomasz Pniewski, Hai Ming Wang, Zhen Lin","doi":"10.4043/30932-ms","DOIUrl":"https://doi.org/10.4043/30932-ms","url":null,"abstract":"\u0000 A critical element in heavy transport design is the identification of design wave conditions. Since most transports are one-of-a-kind, statistically meaningful comparisons of observed vs. design conditions are nonexistent. The present paper examines the experience from a recent oil and gas giga-project, encompassing 56 replicate voyages from Korea to the Suez Canal. In doing so, this paper provides an anchor point for assessing the real-world likelihood of exceeding design wave conditions during heavy transport.\u0000 Voyage maximum wave conditions from the 56 replicate voyages are found to closely follow a Weibull distribution, allowing for the ready evaluation of observed 1-in-N voyage extremes. These observed wave conditions are compared with corresponding design values on both a year-round and seasonal (3-month) basis. Three important observations are drawn from these comparisons. First, operating limits established by heavy transport contractors to avoid waves above a predetermined threshold do not eliminate the need to design for higher wave conditions. Over the 56 replicate voyages studied, observed wave conditions slightly exceeded the contractor's self-imposed operating limit (i.e., by approximately 10% or less) on five separate voyages; on a sixth voyage, this same operating limit was exceeded by approximately 40%. Second, simplified tools for evaluating design wave conditions using Global Wave Statistics do not consistently estimate the 1-in-10 voyage extreme. While the simplified approach is shown to be conservative for the route studied, the associated design margin varies considerably throughout the year. Third, SafeTrans voyage simulations are observed to well-predict the 1-in-10 voyage extreme for the route studied.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"2 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84962756","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":"Propulsion Solution for Icebreaking LNG Carriers","authors":"S. Hanninen, M. Barisic, T. Heideman, Krzysztof Goldon, Sampo Viherialehto, Pirjo Maattanen","doi":"10.4043/31212-ms","DOIUrl":"https://doi.org/10.4043/31212-ms","url":null,"abstract":"\u0000 Since 2007 the traffic volumes in the arctic seas have substantially increased, especially in the North-East Passage following the development of major oil and gas projects. In development of icebreaking LNG tankers the selection of propulsion system is playing a major role determining the vessel performance, safety and icebreaking capability. Recent success of YAMAL LNG project has led to accelerated development of new arctic LNG projects, such as Arctic LNG2. This paper will introduce some outstanding operational results from the revolutionary icebreaking LNG Carriers with modern azimuth propulsion system.\u0000 This paper describes the methodology to use remote diagnostics systems (RDS) onboard ice-going LNG carriers to continually record, consolidate, upload, and analyze ice-breaking propulsion performance. We will further describe how vessel operational experience and RDS data can be used in development of icebreaking LNGC propulsion design and product development.\u0000 The special focus in this paper will be given on propulsion system of large Arctic LNGC equipped with 3 × 15 000 kW azimuth thruster units. These propulsion devices help ship owners to access opportunities in the Arctic areas by providing safe and reliable operation in the region. Paper will highlight some of the key findings from the ship machinery data collected with RDS (Remote Diagnostic system) and further analyzed by engineer specialist in view of ice loading on machinery system and components.\u0000 Podded propulsion solution has played major role on Arctic ship projects, making these challenging projects technically and economically feasible. We will present latest findings and unique results from Arctic LNG carriers, which is valuable information in development of future Arctic oil and gas transportation in the Northern hemisphere.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"11 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82219267","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":"Development and Deployment of the Surface Current Imaging Nowcast System","authors":"P. Anderson, S. Zuckerman, J. Stear, S. Fan","doi":"10.4043/31103-ms","DOIUrl":"https://doi.org/10.4043/31103-ms","url":null,"abstract":"\u0000 This paper describes the development and installation of an ocean surface current monitoring device called SCINS: Surface Current Imaging Nowcast System. We describe the process of designing and building the prototype system, installation on an offshore platform, implementation of real-time reporting, and results from one year of operations.\u0000 SCINS utilizes passive long-wave infrared imaging of the ocean to derive surface currents. This is done using a time-series of images to observe the phase-speed of the ocean waves. Then, the Doppler shift of the observed waves due to the surface current is determined using a non-linear least squares fit. The primary components of SCINS are a long-wave infrared camera and a data acquisition computer. The camera is mounted several 10s of m above the water surface. The system collects imagery at 2 Hz for 5 minutes every 15 minutes, day and night, and calculates surface currents in real-time.\u0000 In this paper, we describe the results from deploying SCINS on an offshore platform, Chevron's Big Foot TLP, in the Gulf of Mexico for one year of continuous data collections, including several tropical storm and hurricane events. Results are compared to environmental data to describe system performance as a function of wind, wave, and sea conditions. We describe the engineering challenges and lessons learned from designing and installing this new type of passive imaging system for offshore use. We conclude that SCINS is an effective method for measuring surface currents in the vicinity of offshore platforms, requiring very little maintenance and without the need to put any instrumentation in the water.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"58 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80921105","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":"Assessment of the Impact of Wax Deposition in a Pre-Salt Project","authors":"N. Pinheiro, Sergio Paulo Gomes Pinho","doi":"10.4043/31243-ms","DOIUrl":"https://doi.org/10.4043/31243-ms","url":null,"abstract":"\u0000 Despite pre-salt fields in Brazil usually having high production per well, one of the areas presents a reservoir with low permoporosity, which results in small flowrates with fluid temperatures during production below the one that is critical for wax deposition. The operations commonly used to remove the wax deposits are diesel soaking and pigging, which brings production losses and OPEX increase. Thus, the economic analysis should consider these events reducing the operational efficiency of production.\u0000 To evaluate the production drop due to wax deposition, it was necessary to perform a loop test to determine the wax growth throughout time. With a multiphase simulator, it is possible to choose the deposition model and the diffusion coefficient that best fits the analyzed fluid. However, one of the limitations of this first analysis is the lack of data to determine the effect of the shear stripping, as the test is performed under a laminar flow. As this term plays an important role in wax growth, it was necessary to add to the simulation model the shear coefficient fitted from another pre-salt field. With this information, it will be possible to make a more reliable evaluation of the impact of wax deposition, increasing the confidence in the production curve, OPEX and NPV of the full field project.\u0000 This paper shows the methodology that has been applied to evaluate the impact of wax deposition in pre-salt fields. It presents the deposition model, and its coefficients used to fit the multiphase transient models to a pre-salt field.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"17 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87785900","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":"Static Reservoir Modeling Comparing Inverse Distance Weighting to Kriging Interpolation Algorithm in Volumetric Estimation. Case Study: Gullfaks Field","authors":"Daniel Asante Otchere, D. Hodgetts, T. Ganat, Najeeb Ullah, Alidu Rashid","doi":"10.4043/30919-ms","DOIUrl":"https://doi.org/10.4043/30919-ms","url":null,"abstract":"\u0000 Understanding and characterizing the behaviour of the subsurface by combining it with a suitable statistical method gives a higher level of confidence in the reservoir model produced. Interpolation of porosity and permeability data with minimum error and high accuracy is, therefore, essential in reservoir modeling. The most widely used interpolation algorithm, kriging, with enough well data is the best linear unbiased estimator. This research sought to compare the applicability and competitiveness of inverse distance weighting (IDW) method using power index of 1, 2 and 4 to kriging when there is sparse data, due to time and budget constraints, to calculate hydrocarbon volumes in a fluvial-deltaic reservoir.\u0000 Interpolation results, estimated from descriptive statistics, were insignificant and showed similar prediction accuracy and consistency but IDW with power index of 1 indicated the least error estimation and higher accuracy. The assessment of hydrocarbon volume calculations also showed a marginal difference below 0.08 between IDW power index of 1 and kriging in the reservoir zones. Reservoir segments cross-validation and correlation analysis results indicate IDW to have no significant difference to kriging with absolute errors of 3% for recoverable oil and 0.7% for recoverable gas. Grid upscaling, which usually causes a loss of geological features and extreme porosity values, did not impact the results but rather complemented the robustness of IDW in both fine and coarse grid upscale.\u0000 With IDW exhibiting least errors and higher accuracy, the volumetric and statistical results confirm that when there are fewer well data in a fluvial-deltaic reservoir, the suitable spatial interpolation choice should be IDW method with a power index of 1.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"106 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86630963","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":"Transformation of Digital Requirements: An Enabler for Successful Complex Projects","authors":"Abe Hudson, J. Marsh","doi":"10.4043/30966-ms","DOIUrl":"https://doi.org/10.4043/30966-ms","url":null,"abstract":"\u0000 This paper discusses the lessons learned from transforming upstream operational requirements from a document environment into a requirements management tool (database). Operations requirements from upstream practices, procedures, specifications, and guides were migrated from a document centric environment into a requirements management system (data centric). Here, requirements were assigned attributes denoting the organization and accountable operational role that requirement. Many organizations, operating complex offshore procedures, especially where operations are highly regulated, are looking to move their operational requirements from a document centric environment to a data centric environment. This paper highlights some potential pitfalls and mitigation strategies for ensuring a successful migration.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"583 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78936304","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":"3D Stress Field Modeling for Wellbore Stability Analysis","authors":"Shaoxuan Li, Lei Liu, Zhilei Han, Rui Wu, Naichuan Guo","doi":"10.4043/31119-ms","DOIUrl":"https://doi.org/10.4043/31119-ms","url":null,"abstract":"\u0000 Borehole collapse is one of the difficult problems in offshore oilfield drilling, which is directly related to regional geostress field. Seismic inversion is widely used to construct 3D stress field, and the accuracy of seismic inversion results depends heavily on the quality of seismic data. Therefore, in the development oilfield with poor seismic data quality, we use attribute modeling method to construct high-precision 3D geostress field to help analyze the wellbore stability of oilfield development wells. First, 3D structural model is created by using seismic interpretation horizon and fault. Then, the 3D stress body is constructed by filling the vertical and horizontal attributes according to certain constraints by using the known geostress values at the wellbore of the drilled development wells.\u0000 P oilfield is a large Neogene oilfield located in Bohai Bay. The serious expansion of the wellbore in the shallow unconsolidated sandstone in the oilfield area leads to high engineering risks. Moreover, due to the influence of large-scale gas cloud area, the effective wave energy on seismic profile is submerged. Through the above attribute modeling method, the high-precision 3D geostress field of P oilfield is successfully constructed. Practical application shows this method is suitable for the evaluation of geostress and wellbore stability analysis in areas with high well control in the middle and late stages of oilfield development. Especially in the area where the seismic data is not reliable enough, the 3D modeling results of this method has higher accuracy than the seismic inversion results.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"21 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82199210","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}