Day 3 Wed, May 08, 2019最新文献

{"title":"A 3D Digital Approach to Flow Assurance","authors":"Reda Bouamra, P. Petit, S. Smuk, Christophe Vielliard","doi":"10.4043/29360-MS","DOIUrl":"https://doi.org/10.4043/29360-MS","url":null,"abstract":"\u0000 The oil and gas industry has long perceived computational fluid dynamics (CFD) as a computationally expensive, high-end simulation method to analyzing extremely complex behavior. However, the recent increase in computational power and the democratization of CFD packages have enabled 3D modeling to become part of the regular in-house execution scope. This paper presents a range of flow assurance CFD applications and shows the impact of 3D workflows in the overall system design, the adoption of standard specifications, and fast-track project executions.\u0000 As oil and gas fluid journeys from the reservoir pore space to production facilities, it faces a wide range of complex flow assurance issues related to the nature of the live production fluids (compositional changes, viscosity, compressibility), the production system environment (high and low pressures) and its interaction with hardware (erosion, flow induced vibration, scaling). One-dimensional mechanistic models are used to solve these flow hindrance issues in wells and pipelines but provide limited results in the complex geometries of subsea and subsurface equipment.\u0000 In subsurface applications, a CFD workflow was used to tune near-wellbore reservoir properties based on advanced 1D and 3D thermal modeling of the completion interval. Accurate thermal modeling was then used to manage downhole flow assurance issues (e.g., asphaltenes and scale buildup). In subsea equipment, the methodology was used to fast-track project execution by using standardized equipment using project specific parameters at an early stage. CFD analyses were used to estimate the risk of erosion and flow-induced vibration in a subsea tree. The thermal aspect was not neglected because CFD conjugated heat transfer was used to detect cold spots and improve the thermal behavior of insulated equipment (trees, manifold) during normal production and shutdown. To avoid long and expensive material qualification campaigns, CFD was used to define the temperature gradient in trees and compare the design temperatures of materials against their calculated temperatures.\u0000 The ability to perform advanced CFD calculations has become a true enabler in the ability to adopt standardized equipment and supplier-led specifications on subsea field development applications, thus contributing to better capital efficiency and shorter time from discovery to production. Several concrete examples from wide-ranging subsea field development projects worldwide are presented to illustrate the added value of CFD in all stages of engineering, from concept definition to project execution.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"78 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83373938","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":"Gas Hydrate Production Testing – Knowledge Gained","authors":"T. Collett","doi":"10.4043/29516-MS","DOIUrl":"https://doi.org/10.4043/29516-MS","url":null,"abstract":"\u0000 Since their initial discovery in the 1960’s, gas hydrates have been considered to be an important potential source of unconventional natural gas. Significant progress has been made relative to our understanding of the geologic and engineering controls on the ultimate energy potential of gas hydrate; however, more work is required to realize the promise of gas hydrates as a future energy source. Gas hydrates have been encountered, recovered or inferred to exist in numerous sedimentary basins in Arctic permafrost settings, regions of alpine permafrost, marine sediments of outer continental margins and in deep lakes. Despite the great abundance of potential gas hydrate resources in the world, a large portion of these resources reside in clay-rich sediments and fracture dominated reservoir systems, and are not generally considered producible with existing technology, but may have future potential with the emergence of new technologies. For a large portion of the world, gas hydrate in sand reservoirs have become a viable production target and the focus of the first production testing efforts.\u0000 Production tests in Arctic Canada (Mackenzie Delta) and Alaska have shown that gas can be produced from highly-concentrated gas hydrate accumulations in coarse-grained (i.e., sand rich) reservoir systems with conventional production technologies. Production can be achieved through the depressurization method and by more complex methods such as molecular substitution (e.g., CO2-CH4 exchange). In 2013, the gas hydrate production test was conducted in a marine setting in the offshore of Japan. An additional test was conducted in Japan in 2017 to further evaluate alternative well completion technologies. Also in 2018, China initiated a 60-day gas hydrate production test in the Shenhu region of the South China Sea.\u0000 This report reviews the results of gas hydrate engineering and production testing studies associated with the Mallik, Mount Elbert, and Iġnik Sikumi projects in northern Canada and Alaska. The results of the marine gas hydrate producing testing efforts in the Nankai Trough (Japan) and in the South China Sea (China) are also summarized.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81900441","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":"Shallow Water Testing of 9 - 12 MVA Variable Speed Drive for Subsea Installation","authors":"H. Lendenmann, T. Laneryd, E. Virtanen, Raphael Cagienard, T. Wagner, Kim Missing","doi":"10.4043/29656-MS","DOIUrl":"https://doi.org/10.4043/29656-MS","url":null,"abstract":"\u0000 The electrical Variable Speed Drive (VSD) system presented is designed for installation on the sea floor to drive nearby electric motors for pumps and gas compressors. A modular concept of the VSD is developed and intended to operate a wide range of subsea motors of powers from 0.5 to 18 MVA, with voltages from 2.0 kV to 7.2 kV or more, and fundamental frequencies up to 300 Hz. Step-out distances from a few km to over 600 km can be accommodated.\u0000 The pressure compensated design effectively removes limits as to the depth of deployment. Pressure compensation is achieved by submerging the drive hardware including the drive transformer in a dielectric liquid which also acts as coolant. The electric power components, including capacitors, semiconductors, and the control electronics are designed with increased margins and redundant hardware, pressure resistance, and materials chosen for compatibility with the dielectric liquid, to achieve a highly reliable design of the overall VSD.\u0000 The drive was deployed into shallow water in a harbor in Vaasa Finland for testing. A top side station was built implementing a \"Power-In-the-Loop\" approach, where the VSD output energy is recovered back into the drive input such that the grid supply only provides the lost power, but not the much higher circulated power.\u0000 The drive operated more than 1000 h at 22 kV input and 6.9 - 7.2 kV output voltage at different power levels. We conclude from this first shallow water test, that all components of the VSD system work properly together up to 1000 A output current. Different operation conditions reflecting the envisioned application, including redundancy capability were successfully tested. The thermal performance was extensively verified, including an optional external heat exchanger to achieve high ratings even in warm waters.\u0000 To our knowledge this is the first time a medium voltage drive is operated at 9 to 12 MVA for an extended time submerged in a sea water environment. All its modules are designed to operate down to depths of 10’000 ft / 3000 m or more and are concluding qualification according to API17F and SEPS 1002.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"35 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88493223","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 for Drilling Operations – Towards Cloud-Based Operational Planning","authors":"L. Pivano, D. Nguyen, K. Ludvigsen","doi":"10.4043/29316-MS","DOIUrl":"https://doi.org/10.4043/29316-MS","url":null,"abstract":"\u0000 Most drilling operations in deep water are performed in Dynamic Positioning (DP) mode. In harsh environments and shallow water conditions, thruster assisted position mooring configurations are often the preferred choice as the mooring lines provide an extra help to counteract the environmental loads. Drilling operations, both in pure DP or thruster-assisted position mooring modes, are limited by the ability of the vessel to maintain position and heading within the required accuracy. In addition, the motion in heave, roll and pitch must be within predefined limits. These limits vary between the type of operation to be performed. For example, reconnecting the low marine riser package has much stricter motion limitations compared to logging or drilling through riser operations. All these operations need to be carefully planned; and having estimate in advance of the vessel motion and station-keeping performance could be of vital importance, also considering planned maintenance.\u0000 The aim of this paper is to share experiences in planning DP drilling operations by using cloud-based time-domain simulations performed with a digital twin of a semi-submersible drilling rig. A digital twin is a virtual representation of an asset, used from early design through building and operations, maintained and easily accessible throughout its lifecycle. A digital twin can replicate many aspects of the asset; in the case of planning DP drilling operations, our digital twin includes time-domain models for running simulations and predicting the vessel motion.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"32 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74799629","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":"Petrophysical Evaluation of Gas-Hydrate Formations in National Gas Hydrates Programme Expedition 02 in India","authors":"Sikha Rani Mondal, K. Chopra","doi":"10.4043/29614-MS","DOIUrl":"https://doi.org/10.4043/29614-MS","url":null,"abstract":"\u0000 Gas hydrates are naturally-occurring crystalline inclusion compounds. They comprise compressed molecules of gas (usually methane) that are ‘lodged’ within a solid lattice of water molecules. For this reason, the gas molecules are called ‘guests’ and the water molecules are called ‘hosts’. Gas hydrates form where there are sources of water and methane under favorable thermodynamic conditions of relatively high pressure and low temperature.\u0000 Objective of the study is to evaluate Petrophysical Properties from drilled well of NGHP expedition 2 for Gas Hydrate. To identify different hydrate formation and estimation of hydrate saturation.\u0000 The Work flow to estimate Petrophysical properties is guided by the high resistivity, low transit time and low density. It includes evaluation of different overlays and cross plots of wells like picket plot to firm up different parameters. Porosity is measured by density log, water saturation using Archie's equation; gas hydrate saturation using DMR method and its validation for the results obtained from Pressure core.\u0000 Electrical resistivity and acoustic travel time mainly used to identify potential Gas Hydrate zones with overlay technique from density porosity and acoustic travel time and other density porosity with total NMR porosity, along with resistivity log are used for identifying potential Gas Hydrate zones in this study. Porosity estimated from density log is used for calculation Hydrate saturation. Gas Hydrate saturation is estimated using standard Archie's equation and Density Magnetic Resonance (DMR) method. Wherever NMR log data is good, saturation estimated from both are in good agreement. Log derived Gas Hydrate saturation are compared and validated with Gas Hydrate saturation obtained from pressure cores. Very good Gas Hydrate saturated zones are observed above BSR in 21 wells in the range of 40-90%. Out of these 21 wells, 16 wells are also having Gas Hydrate saturation in the range of 30-50%. Good Gas Hydrate saturation wells are mainly in area B and C in KG deep water Basin. This study will be very useful in preparation of Geological model for estimation of Gas Hydrate reservesaccurately. This study will also help in NGHP-3 for identifying suitable sites to carry out pilot production testing of Gas Hydrates.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"87 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90933494","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":"The Reduced-Draft Spar: A Novel Cost-Effective Concept for Floating Offshore Wind Turbines","authors":"S. Guzman, M. Taboada, Albino Pombo, R. Martín, Ana Bezunartea, Andy Knights-Cooper, J. Moreu","doi":"10.4043/29495-MS","DOIUrl":"https://doi.org/10.4043/29495-MS","url":null,"abstract":"\u0000 This paper describes the conceptual design and estimates the CAPEX breakdown of a novel floater type for offshore wind turbines: the Reduced-Draft Spar (RDS). This floater, which resembles a GBS although it is in essence a spar, has excellent seakeeping at a reduced draft.\u0000 Aiming at reducing the CAPEX, the RDS design allows the installation of the wind turbine at the manufacturing site. Furthermore, no auxiliary means are required to provide stability during towing and in-place installation (mooring and electric hook-up, and ballasting to the operational draft). It also promotes the use of structural concrete and cost-effective high-density ballast for its construction. In addition, the whole concept benefits from the implementation of an Active Ballast System (ABS) to compensate the mean tilt angle while operating.\u0000 An extensive model test campaign was carried out in summer 2018 at INTA-CEHIPAR model basin to validate the concept. The tests scope was focused on calibrating a state-of-the-art numerical hydrodynamic model for further stages of development. An 8MW RDS model, with a scale factor of 1:50 and a 3-line spread mooring system, was tested in Transport and Installation (T&I), operational and survival conditions to assess the concept feasibility. The ABS was simulated using pre-calibrated counteracting weights. Stability during T&I was also checked.\u0000 In addition, the unit CAPEX was estimated and compared to equivalent semi and spar units made of steel. The RDS can operate at intermediate water depths (60 to 80 m, where spars cannot) and deep waters, and also avoids the use of expensive auxiliary means for T&I. The results from the model tests confirm a dynamic behavior of the RDS similar to that of classic spars, which is beneficial for the offshore WT. Regarding the CAPEX, estimations indicate relevant savings compared to classic spars or semis.\u0000 Although it is a large massive unit, the use of concrete combined with heavy ballast makes the concept feasible. Due to the ABS, the required platform's size is smaller and the fatigue life of the WT components increases. Furthermore, an adequate ABS control system increases the net energy production since the energy consumption is negligible compared to the extra generated power. The use of civil construction manufacturing technologies such as floating docks and assemble of pre-manufactured parts leads to major CAPEX savings.\u0000 The US coast has a huge offshore wind energy resource at water depths greater than 60m, where the RDS floating concept has a promising future. The concept could be used as well in the Offshore Oil& Gas.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"108 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91336241","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":"Offshore LNG Mega-Module Solution","authors":"J. Dimbour, Loic Ferron, Eric Luquiau, Benoît Laflotte","doi":"10.4043/29633-MS","DOIUrl":"https://doi.org/10.4043/29633-MS","url":null,"abstract":"\u0000 Offshore floating LNG can offer an optimum CAPEX solution either for the development of large or stranded gas fields, including full processing functions, or as an enabler to oil production while monetizating associated gas.\u0000 The offshore LNG mega-module solution was developed to meet the challenge of producing competitive LNG offshore, leading to the next generation of floating LNG facilities.\u0000 This paper decribes the offshore LNG mega-module innovative solution of which the features are patent pending. The design features are highlighted, then the specifics of combining topsides with hull are presented, followed by the installation particulars. Finally, perspectives and savings in using this solution are presented.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"174 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86806528","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":"Risks Minimization and Results Improvement in Offshore Projects","authors":"Hongfu Shi, Wei Zhang, Xiaodong Han, Haochuan Ling, Chaojie Kong","doi":"10.4043/29325-MS","DOIUrl":"https://doi.org/10.4043/29325-MS","url":null,"abstract":"\u0000 A new regional integrated development pattern is proposed by Bohai Oilfield Bureau, based on the existing development and production system and engineering facilities, and combined with the distribution characteristics of underground oil and gas resources in Bohai oilfields, and according to the principles of ‘overall planning, unified layout, stage promotion and subarea implementation'. Through the integration and rational allocation of exploration and development, reservoir and engineering, development and production, the overall planning of underground resources and ground engineering is carried out, and a perfect regional development pattern is gradually formed. Based on reducing the threshold of oilfield development through resources sharing and accelerating the construction of new oilfield, the reservoir potential is fully released, and the efficient development of regional oil and gas is realized.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"258 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76203807","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":"Subsea Demulsifier Injection to Enhance Crude Oil Production in Offshore Brownfields - A Success Case","authors":"M. Oliveira, Monica Alevatto, T. P. Sampaio, P. Dias","doi":"10.4043/29535-MS","DOIUrl":"https://doi.org/10.4043/29535-MS","url":null,"abstract":"\u0000 In Brazil oilfield scenario, there are large, clearly identified brownfield sites, many of which with high additional oil production potential. The lifting costs and conventional breakeven price per barrel associated with an existing producing field offshore, even those in decline and requiring some recompletion & workover jobs, are – in many situations - less investiment demanding than brand new greenfield development.\u0000 The formation of water in oil (W/O) emulsions is ubiquitous in oilfield production. As the water commingled in crude increases, the emulsions' stability and viscosity also increase, thence generating flow restrictions due to higher friction losses. The subsea demulsifier injection has proven to be an interesting alternative to overcome this flowing constraint in mature wells, thus maximizing the productive capacity of existing brownfields. This paper presents some results and challenges faced to implement the routine of subsea demulsifier injection, from the development of testing protocols to come up with a tailor-made chemical solution, to the hurdles associated to chemical injection through subsea umbilical- and gas lift-lines.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"52 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76258837","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":"Operators Optimize High-Pressure/High-Temperature and Ultrahigh-Pressure Perforation Strategies Using Laboratory Testing","authors":"B. Grove, R. DeHart, J. McGregor, Haggerty Dennis, C. Christopher","doi":"10.4043/29611-MS","DOIUrl":"https://doi.org/10.4043/29611-MS","url":null,"abstract":"\u0000 Multiple perforation laboratory programs have been conducted during recent years to support high-pressure/high-temperature (HP/HT) and ultrahigh-pressure (UHP) oil and gas field developments at various offshore locations globally. This paper highlights six such projects that supported activities within the Asia-Pacific, North Sea, and US Gulf of Mexico (GOM) (both Miocene and Lower Tertiary) regions. Each program was designed and conducted in collaboration with an operator and field operations personnel to help reduce potential risks, improve operational efficiency, and optimize well performance across a variety of challenging environments.\u0000 Laboratory experiments were based on API RP 19B Sections 2 and 4, with test conditions customized to match specific downhole environments of interest (rock and fluid properties, stress, pressure, temperature, and flow scenarios). Matching downhole conditions at the laboratory proved important because this yields results that can be quite different from those obtained at surface (or scaled) test conditions. Reliable estimations of field perforation skin, sanding propensity, and the effectiveness of subsequent stimulation operations depend on realistic perforation and flow data obtained at relevant downhole conditions. The overriding goal for test design is to create and expose the laboratory perforation in an environment that matches its field counterpart as closely as possible. Beyond obtaining accurate flow data for skin and/or sanding propensity determination, post-test diagnostics, such as computed tomography (CT) and optical techniques, provide additional essential insight into the characteristics of the perforation tunnel, core interior, and the hole through the casing and cement.\u0000 Results from these various programs were used to confirm or, in some cases, guide the field perforating strategy.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"53 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76394752","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}