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Search operation: production test
...SPE 16555/1 TROLL HIGH RATE PRODUCTION TEST, PLANNING AND EXECUTION B. H. Nilssen Norsk Hydro Copyrtght 1987, Society of Petroleum EnglnHra T...on elsewhere is usually granted upon request provided proper credit is made. SUMMARY The high rate production test performed by Norsk Hydro on the Troll East structure during the summer of 1985 with the semi submer... number of specially designed, modified or adapted equipment items were used in order to fulfil the test objectives and maintain safe operations. These were: Jetting tool for casing cleaning. Gravel pack ...
...SPE 16555/2 TROLL HIGH RATE PRODUCTION TEST, PLANNING AND EXECUTION r L Objective No. 1 differed mainly from a conventional well ...test in that "high rate" meant a rate of up to 4.25 x 106 sM3/D (150 mm scf/D). The highest gas ...test rate previously obtained by Norsk Hydro on the Troll East structure using conventional drill stem ...
...SPE 16555/4 TROLL HIGH RATE PRODUCTION TEST, PLANNING AND EXECUTION The main ...test string was composed of the items as listed and described below "Fig. 2, 3, 4 and 5". Flapper valve ...875 inch nipple profile was installed immediately below the seal assembly for pressure testing. The test plug was run on wireline when required. Seal assembly A 6 inch OD standard floating seal assembly w...
Summary The high rate production test performed by Norsk Hydro on the Troll East structure during the summer of 1985 with the semi submersible drilling rig Treasure Seeker required that a large number of specially designed, modified or adapted equipment items were used in order to fulfil the test objectives and maintain safe operations. These were:Jetting tool for casing cleaning. Gravel pack floor manifold to ease operations. Surface read out of downhole pressure and temperature through cable on the outside of the tubing. 3 inch I.D. tester valve. 3.7 inch I.D. annulus pressure operated kill valve. Full bore double gauge carrier. 5 inch I.D. sub-sea test valve. 5 inch I.D. lubricator valve. 5 1/8 inch bore flowhead. Vertical high capacity separator. 32 channel data logger. The use of this equipment together with other more commonly used equipment made the test a success. Introduction Prior to drilling well 31/6-8 on the Troll East structure the decision to perform a (record) high rate gas test on the well, providing the required reservoir thickness and qualities were found, had been taken. The test objectives were:Define reservoir inflow performance at high and low rates. Obtain test permeabilities and skin. Obtain representative fluid samples. Investigate pressure and temperature drops in the completion and tubing at low and high rates. Define maximum productivity of the well system. Optimize data acquisition of the well system.
...FEATURE ARTICLE New Technique Provides Open-Hole Production Test of Wildcat Formations LYNES, INC. B. C. MALONE MIDLAND, TEX. ERNEST W. STOKEY HOUSTON, TEX. JUNIOR...ture treatment on the formation It is becoming increasingly (lifficuIt The conventional drill-stern test is in order to obtain a better indication to find proved oil reserves within the the most widely us...valuation of the Under present conventional standards, general, companies must drill much potential production of a formation. high-pressure treating and prolonged deeper in their search for oil. When pressures...
...for Success of New ing device. This tool position provides closed-in drill pipe and tool containing Production Test a means to circulate and condition a formation ...test. Since the tubing is the mud to a reasonable degree without pulled dry, the blowout hazard of Washe...d-out Sections making round trips. Another valuable pulling test samples of oil and gas Up-hole zones are subjected to a use of the position is to circulate is elim...
... trips. Also, the tool may After completion of treating and be moved in the hole to locate packer production swab testing, the tubing is seats if first set in a section with vertical loaded with the drilling...rt the formation with acid before beginning high anchoring ability to the tool. This an open-hole production test. is accomplished by the inflatable body This may be accomplished by locking of the packer element ...dle tool used to obtain is accomplished by increasing the volume the top end of the packer element. production tests on up-hole zones in a of the packer body. This volume Inflatable packer elements with two wil...
Introduction It is becoming increasingly difficult to find proved oil reserves within the boundaries of the United States. In general, companies must drill much deeper in their search for oil. The depth of present-day wildcat wells and the complex completion procedures used on such wells have brought about a large increase in the cost to put oil back in the tank battery. This skyrocketing of costs has stimulated a constant search for new or improved methods in every phase of drilling for oil. A new testing technique which has helped to a great extent the struggle to cut the cost of finding oil reserves provides conclusive evaluation of questionable wildcat formations without the expense of running casing. The technique and tools used were made available to the petroleum industry in the latter part of 1956. To date, conclusive information has been obtained on more than 200 wildcat formations located in Arizona, Utah, New Mexico, Colorado, Wyoming, Kansas, Oklahoma, Illinois, the Texas Panhandle, North Central Texas, the Permian Basin of West Texas, and Southwest Texas. Successful open-hole production tests have been performed in porous lime, consolidated lime, fractured lime, vugular lime, conglomerate, consolidated sand, coarse sand, shaly sand and red shale. Need of Supplement For Conventional Testing The conventional drill-stem test is the most widely used method to obtain information for the evaluation of the potential production of a formation. When pressures and fluid are obtained in sufficient amounts, the drill-stem test gives exact and conclusive in formation on formation potential. However, quite often a drill-stem test is either void or obtains very little yield of fluid or pressure. This would lead to the normal conclusion of poor production potential. When electric logs indicate possible fluid and a void drill-stem test results, it is possible that the formation has been blocked or plugged by the drilling mud. This blocking action can be of varying degrees. A partial block may occur to give only a slight show of formation pressures and fluid and, thus, indicate poor potential. Therefore, when test results are poor but logs give indication of production, the test is inconclusive. It then becomes necessary or desirable to more thoroughly test the zone, or zones. In order to obtain more conclusive in formation under such conditions, an acid treatment may be required to break down the suspected mud block. When the mud block has extended well into a permeable zone, a substantial treatment is often necessary. Very high pressures normally occur while breaking through these blocked permeable zones.
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (21 more...)
...SPE-172515-MS Keeping up With Technological Advances - An Innovative Approach to Validate Production Test Data M.N. Khan, and T. Felix Menchaca, Abu Dhabi Marine Operating Company Copyright 2015, Society... reservoir performance data than in the past. Multi-Phase Flow Metering is an expedient addition in production testing domain. As per the recent statistics, globally, approximately 4000 Multi-Phase Flow Meters ...shing and implementing the appropriate data validation workflows on the MPFM data. The conventional production test data validation approach can be applied to the MPFM measurements up to a certain extent, but in ord...
...ct viability analysis y Geologist for the validation of geological conceptual model In the past the production data acquisition could only be carried out with the help of the ...test separator where monophasic flow rate measurements are taken at separator's liquid and gas outlets. ...Depending upon the fluid type and the test objectives, a number of additional equipment is usually required to carry out the ...
...stream. Eq.1 is applied directly for the 2-phase measurement case, whereas, when both oil and water production rates are above minimum cut off and the ...test separator is operated in 3-phase, the flow rate computation for both oil and water is carried out a...asured and reported by the meter itself. Ideally this meter factor should be determined during each production test. Shrinkage factor '1-Shr' is ratio of volume at liquid (in fact oil) at the metering conditions to ...
Abstract The technological advances in oil and gas industry are enabling the operating companies to monitor their hydrocarbon reservoirs closely. Today reservoir surveillance engineers are able to acquire more well/reservoir performance data than in the past. Multi-Phase Flow Metering is an expedient addition in production testing domain. As per the recent statistics, globally, approximately 4000 Multi-Phase Flow Meters (MPFM) installations are providing reliable measurements under different applications. As with any new technology the philosophy behind MPFM measurements is blurry for many users, who find difficulty establishing and implementing the appropriate data validation workflows on the MPFM data. The conventional production test data validation approach can be applied to the MPFM measurements up to a certain extent, but in order to find the source of discrepancies in MPFM data, additional processes are required to be included in the workflow. The production history of the majority of hydrocarbon reservoirs in the world was built on conventional test separator flow rate data. Introducing a new measurement technology with different set of accuracies and different working principles has been a challenge for the production data users. To standardize the data validation process, a systematic approach can be implemented to validate the production testing data from different sources, which not only will help the end users to gain confidence in MPFM flow measurements but also will assist identifying the sources of discrepancy in MPFM measurements during day to day operations. This paper will explain the stepwise data validation approach that can benefit different production test data users in oil and gas industry.
...OTC-24719-MS Design of the Surface Flow Test System for 1st Offshore ...Production Test of Methane Hydrate Yoshihiro Terao, SPE, Japan Oil, Gas and Metals National Corporation; Kevin Lay...ct must contain conspicuous acknowledgment of OTC copyright. Abstract This was the first offshore production test of This paper describes the design and operation of methane hydrate to have been conducted in the t...
...conduits. The separated gas was produced through 6-5/8" drill pipe inside the marine Outline of the production test operation riser, and the pumped water was produced through The ...test location was selected in the Eastern the subsea choke line in the marine riser system. Nankai Troug...h area off the Pacific Coast of Honshu The surface flow test system was designed to Island where highly concentrated methane hydrate safely manage the produced ...
...al sand filter system to remove with slug handling capability for the gas train. the solids, a well test choke manifold for flow control - For the water train, a standalone work valve was and a two-phase ...ining methanol was required in case of gas produced to surface via the 6-5/8" drill string and flow test shutdown and re-start operations. surface ...test tree. The gas was directed to a separate To select the appropriate surface flow system, flare line ...
Description: As a paper of the MH21 study, this paper describes the design and operation of the surface flow test system utilized for the 1st Offshore Production Test of Methane Hydrate in deep water offshore Japan in March 2013 using a dynamically positioned drill ship. The unique characteristics of this production test required a customized approach to the design of this system. As the production test was carried out for scientific research purposes, the data acquisition requirements were of paramount importance. Application: The information contained in this paper can be applied to future offshore production tests of methane hydrate using the depressurization technique. Results, Observations, and Conclusions: The surface flow test system was successfully designed, installed, commissioned and operated. Measurement and separation of the produced gas and water were effectively achieved under low temperature, low pressure, and low production rate conditions. Transportation and operation of surface flow test equipment was able to accommodate the motions of the floating drilling vessel. Two separate fluid processing trains were installed for high quality measurement of the gas and water rates. A real time data sharing system to monitor the condition of the surface system and the down hole systems implemented but shut down of the downhole equipment was not triggered automatically by surface production equipment ESD. Some non-critical data acquisition failures occurred or limitations observed during the production test. Significance of Subject Matter: It is believed that this was the first offshore production test of methane hydrate to have been conducted in the world. The design philosophy and operational experience will be useful for future production testing in similar environments.
- Asia > Japan (0.91)
- North America > Canada (0.68)
Operational overview of the first offshore production test of methane hydrates in the Eastern Nankai Trough
Yamamoto, Koji (Japan Oil, Gas and Metals National Corporation) | Terao, Yoshihiro (Japan Oil, Gas and Metals National Corporation) | Fujii, Tesuya (Japan Oil, Gas and Metals National Corporation) | Ikawa, Terumichi (Japan Petroleum Exploration Co. Ltd.) | Seki, Makoto (Japan Petroleum Exploration Co. Ltd.) | Matsuzawa, Maki (Japan Drilling Company) | Kanno, Takayuki (Schlumberger KK)
...OTC-25243-MS Operational overview of the first offshore production test of methane hydrates in the Eastern Nankai Trough Koji Yamamoto, Yoshihiro Terao, and Tesuya Fujii,...ous acknowledgment of OTC copyright. Abstract In March 2013, the world's first field trial of gas production from marine methane hydrate deposits was conducted in the Daini Atsumi Knoll area of the Eastern Na...issociate the ice-like material was "depressurization method" that had been applied in the previous production test in Mallik site, the Northwest Territories, Canada in 2007-2008. Japan Oil, Gas and Metals National ...
...sical logging data taken in the past surveys, and an additional geotechnical site survey in 2011, a test site was selected in the north slope of Daini Atsumi Knoll. As the world's first offshore ...production trial of gas from methane hydrates below seafloor, main objectives of the ...test are defined as 1) confirmation of productivity in an offshore methane hydrate well in short duratio...
...OTC-25243-MS 3 Figure 1--Test location of the first offshore ...production test of methane hydrate in the eastern Nankai Trough (AT1 site) with BSR distribution. Figure 2--A seis...mic section near the production test site. Clear BSR and MHCZ are seen. In 2011, geo-hazard surveys were conducted for seafloor stabili...
Abstract In March 2013, the world's first field trial of gas production from marine methane hydrate deposits was conducted in the Daini Atsumi Knoll area of the Eastern Nankai Trough off the Pacific coast of Japan as a process to bring gas hydrates under seafloor to valuable energy resource. The technique used to dissociate the ice-like material was "depressurization method" that had been applied in the previous production test in Mallik site, the Northwest Territories, Canada in 2007-2008. Japan Oil, Gas and Metals National Corporation (JOGMEC) as a part of MH21, the Research Consortium for Methane Hydrate Resources in Japan planed and supervised the project with the funding of the Ministry of Economy, Trade and Industry (METI), and scientific supports from the National Institute of Advance Industrial Science and Technology (AIST). One production well with two monitoring boreholes were drilled in the test site for the test. Along with the flow test operation, intensive data acquisition program was planned and implemented to understand behavior of methane hydrate dissociation- bearing sediments against depressurization. To realize high degree of drawdown in relatively shallow formation below deepwater, several downhole devices were designed and installed. The flow test started in the morning of March 12 and lasted until severe sand production forced to terminate the operation six days later. During the stable production term, gas flow rate was approximately 20,000m under atmospheric condition, and gas liquid ratio was larger than 100. A lot of data including formation temperatures, fluid pressure and temperature, and physical property changes in the formation were obtained. The data taken are under studies to verify applicability of the depressurization technique as a methane hydrate production technologies.
- Asia > Japan (1.00)
- North America > United States (0.94)
- North America > Canada > Northwest Territories (0.49)
- Geophysics > Seismic Surveying (0.69)
- Geophysics > Borehole Geophysics (0.47)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Japan Government (0.70)
New Insights on Acid Stimulation of Sour Gas Wells With Flowback To Facilities Without Production Test Equipment
Paige, Stephen (Nederlandse Aardolie Maatschappij B.V., Assen, Netherlands) | Redder, Jos (Nederlandse Aardolie Maatschappij B.V., Assen, Netherlands) | Shepherd, Andrew G. (Nederlandse Aardolie Maatschappij B.V., Assen, Netherlands)
...SPE 159121 New Insights on Acid Stimulation of Sour Gas Wells With Flowback To Facilities Without Production Test Equipment Stephen Paige, Jos Redder, Andrew G. Shepherd, Nederlandse Aardolie Maatschappij B.V., A...jective of the campaign was to reduce operational costs by flowing the wells back directly into the production facilities after the treatment, without the use of temporary ...production test equipment. This strategy would be considered successful, if it could be proven to be technically we...
...ing the stimulation campaign, the following insights were gained: - It was possible to increase gas production in poorly performing wells using a cost-effective stimulation campaign without the use of temporary... production test equipment - Selection of an adequate stimulation formulation, including corrosion inhibitor, was a ...
...observed that the majority of these wells are high temperature ( 100 o C). Included are the gas production figures just prior to the stimulation campaign. The average ...production value was 17,000 Nm 3 /day ( 600 Mscf/day) which represents around 1% of the total daily ...production of the ...
Abstract This paper describes some of the operational aspects, planning practices and improvements in both coil tubing and bullhead acid stimulation campaigns carried out to increase the performance of gas-producing wells in a mature sour-gas asset. The objective of the campaign was to reduce operational costs by flowing the wells back directly into the production facilities after the treatment, without the use of temporary production test equipment. This strategy would be considered successful, if it could be proven to be technically well-executed, and compliant with HSSE directives. By engaging in a multi-disciplinary approach, critical aspects of this campaign were identified at an early stage, including selection of fit-for-purpose stimulation formulation. Furthermore a novel corrosion inhibitor capable of withstanding unspent acid in a sour system was deployed in the facilities for integrity and protection. Key performance indicators for the campaign were set, including target pH values for flowback samples. Monitoring of H2S concentration of the produced gas was carried out, and control with the use of a H2S scavenger injected in well flowlines allowed for export gas specifications to be maintained. Overall the campaign generated significant productivity improvements. This cost-effective acid stimulation is therefore a valuable tool for well reservoir and facilities management in the asset.
...SPE-187749-MS A New Approach to Test Production of Exploration Wells in the Territory of Eastern Siberia. N. M. Dadakin, RN-KrasnoyarskNIPIneft, L...infrastructures, the lack of a well surface facility system and the oil preparation system to start production. This report describes an example of a trial operation of a remote prospecting well that includes a...des recommendations for the adoption of technologies for pilot operation based on the block-modular production complexes for the early ...
...oject documents, a set of surveying works to explore the rock section that composes the deposit, to test and perform trials of all entered formations, shall be carried out during exploration of deposits f...l operation. Trial operation of prospecting wells implies a set of works carried out to specify the production capacity of wells, composition and physical and chemical properties of formation fluids, operationa...ristics necessary for planning the field development; - carry out a long-term pressure transient test of wells to estimate the drainage area and the formation boundaries; - evaluate operational risk...
... select a software model that would correctly replicate the bottomhole pressure at given registered production rates. Then, based on the obtained model, ...test designs of all interpretations are prepared and a forecast of the behavior of bottomhole pressure i...he expected decline rates. Upon completion of all preparatory works, it is necessary to perform the test design of the first pressure buildup curve study after the first ...
Abstract Trial operation of prospecting and exploratory wells tends to be affected by the remoteness of the field from the main transportation routes, weakly developed industry, energy, and transport infrastructures, the lack of a well surface facility system and the oil preparation system to start production. This report describes an example of a trial operation of a remote prospecting well that includes all pre-development works, a surveying program that allows obtaining the maximum information about the productive horizon in a short time. It also provides recommendations for the adoption of technologies for pilot operation based on the block-modular production complexes for the early production launch of exploratory and prospecting wells or individual sections of the field, and technologies for continuous well monitoring and management, including bottomhole pressure gauges, a distributed temperature sensing system and a system for real-time data receiving and transmitting to the subsoil user. This approach allows us not only talking about early production, but also solving a number of tasks, e.g. petroleum evaluation, extraction capacities of a deposit, drainage area, formation pressure evaluation, optimal well operation mode identification, gas/oil ratio change estimates, water cut, and other geological tasks. The report also describes the key drawbacks of applied trial operation methods and technologies as compared to the proposed technologies.
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- (3 more...)
...,:" OTC 7221 Snorre Subsea Production Systems: Land ...Test and Installation Experience Ingar Overgaard, Saga Petroleum as.; B.D. Boles, Esso Norge as; and f3...nd by whom the paper is "prasented. ABSTRACT Installation weight was 2,400 tonnes. The design oil production capacity is 9,300 cubic metres per day Installation of equipment has been completed in (approximat...
...2 Snorre Subsea Production System - Land ...Test and Installation Experience OTC 7221 perform operator training, and minimal, however one problem w...ocedures, last piece of equipment was fit into the last wellbay. This demonstrates the necessity to test the complete The ...
...4 Snorre Subsea Production System - Land ...Test and Installation Experience OTC 7221 A haul-down wire is used for the final positioning and proces...s of the subsea related equipment. Pull-in and connection important to start sea trials in a simple test of the flexible risers and umbilicals at the TLP went environment to maintain safety and then move ...
ABSTRACT Installation of equipment has been completed in preparation for production start of the first subsea well in the Snorre Field Development Project. The ten well Subsea Production System (SPS) is located in 335 m of water, 6 km away from the Tension Leg Platform (TLP). A comprehensive job was performed by several Engineering, Procurement, and Construction (EPC) contractors, both in meeting contractual milestones and providing adequate subsystems which compose the Snorre SPS. The system has earlier been described in OTC papers 6202 (Ref. 1) and 6625 (Ref. 2). This follow-up paper expands the discussion to cover a thorough land test of the system with elements of subsea testing for critical components, a description of the installation of the template and manifold, and the flowlines and umbilicals, commissioning activities on board the TLP, the drilling and completion approach including installation of the first subsea tree, and the use of a relatively sophisticated Remotely Operated Maintenance Vehicle. BRIEF SYSTEM DESCRIPTION The Snorre Subsea Production System is shown in Fig. 1, which identifies the various sub-systems. It can accommodate 10 wells at one time, and with a 10+ 10 well arrangement, the plan is to drill approximately 20 wells from it without reuse of slots. The template and manifold is 48 metres long, 32 metres wide, and (including the 3 metres skirts) 19 metres tall. Installation weight was 2,400 tonnes. The design oil production capacity is 9,300 cubic metres per day (approximately 58,500 bopd). Special features of the system include:guidelineless handling of equipment, TFL (through flowline) capabilities universal manifold, i.e. each well slot can be tied into either a low or high pressure production header or a water injection header, designed for simultaneous drilling and production as well as maintenance, and diverless maintenance. SYSTEM LAND TEST A comprehensive program of testing equipment delivered by the EPC contractors began immediately following the delivery of the template and manifold to Saga in March 1991. At this point, the control system was integrated within the manifold, one of the subsea trees and associated running/handling tools were available, the flowline and umbilical pull-in and connection equipment was delivered, and short lengths of the flowlines were available for interface testing. The Remotely Operated Maintenance Vehicle (ROMV) would come to the test site some months later for interface and operational checks. The land test program was established to:check interfaces between equipment verify functionality of the control system, confirm TFL tool and pig passage through the manifold, perform operator training, and verify commissioning and operational procedures, The test program was established to verify those interfaces which had not been previously tested and to confirm dimensional aspects of equipment from different contractors. The flowline and umbilical end connections were test fit and interchanged before being returned to the contractors for fit to the actual flowlines and umbilicals. The subsea tree was test fit in all wellbays, both inner and outer slots. During this process, the control system was checked wellbay by wellbay for proper function.
- North America > United States > Texas (0.28)
- Europe > Norway > North Sea > Northern North Sea (0.24)
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > PL 375 > Block 34/7 > Snorre Field > Statfjord Group (0.99)
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > PL 375 > Block 34/7 > Snorre Field > Lunde Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > PL 375 > Block 34/4 > Snorre Field > Statfjord Group (0.99)
- (9 more...)
Real-Time Surveillance - How System Integration Minimises Deferment, Optimises Production, Maximises Test Unit Capacity and Tracks Well Operating Envelopes
Al Balushi, Mahmood (Brunei Shell Petroleum Co Sdn Bhd) | Konwar, Anupam (Brunei Shell Petroleum Co Sdn Bhd) | Abdullah, Zulfikri (Brunei Shell Petroleum Co Sdn Bhd) | Sahu, Sambit-Kumar (Shell Projects and Technology India) | Briers, Jan (Shell Projects and Technology Malaysia)
...SPE 165760 Real-Time Surveillance - How System Integration Minimises Deferment, Optimises Production, Maximises ...Test Unit Capacity and Tracks Well Operating Envelopes Mahmood Al Balushi, Anupam Konwar, SPE, Zulfikri...ssue in upstream E&P operations is how to manage wells and reservoirs more effectively. Oil and gas production from onshore and offshore wells can be relatively difficult to manage, not only because of multipha...
...2 SPE 165760 Production Universe is a data driven modelling application developed by Shell to provide real-time well-by-wel...l production estimates in three phases (oil, gas and water). Physical measurements like well tubing diameters, p...flow correlations are not used. Real-time well measurements are related to volumetric flow from the test separator. This data-driven approach has been proven to be robust, usable and sustainable in the oi...
...only those wells which have a discrepancy between the PU and EC status. This tremendously helps the production programmers and operations to just focus on the discrepancies rather than having to monitor every w...ell across the asset. The tool also highlights the production estimate of each well, which helps the operations to prioritize their activities in the field in or... Figure 1: PU-EC Comparison EBS tool to identify hidden deferments On an average, using this tool, production programmers save up to 1 hour per day per programmer for the daily surveillance of their wells. The...
Abstract A key issue in upstream E&P operations is how to manage wells and reservoirs more effectively. Oil and gas production from onshore and offshore wells can be relatively difficult to manage, not only because of multiphase nature of the well production, but also due to lack of a continuous, reliable measurement of well/reservoir performance. Reporting continuous production from the wells and performing hydrocarbon allocation with credible accuracy is an area with many challenges in upstream E&P operations. Shell's Production Universe (PU) is a novel software application developed by Shell to address some fundamental gaps in the management and surveillance of oil and gas production systems. Using data driven models, it is designed to estimate and optimize the production (and injection) of wells continuously in real-time, based on the available wellhead instrumentation. PU provides improved well surveillance, more accurate hydrocarbon accounting, and automatic production reporting and production optimization. The data from PU can also be used for quick analysis to safeguard the technical integrity of wells and reservoirs. It is also cost-effective in that it requires minimal commodity instrumentation and IT systems, much of which may already be present in field operations. Brunei Shell Petroleum (BSP) in South East Asia had adopted the PU technology just after it was launched in 2004. Today, BSP continues to deploy PU in all of its assets. Implementation of PU in BSP has helped in exception based surveillance, analysis and troubleshooting; and hence has helped optimized resources being directed towards production optimization activities. It has also improved data quality and reporting. This paper discusses how Production Universe has been instrumental in helping BSP in the above operational and production areas. In particular, the application of PU in various facets of WRFM (Wells, Reservoir and Facility Management) to achieve operational excellence is discussed.
- Asia (1.00)
- North America > United States > Texas (0.28)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- Production and Well Operations > Well Operations and Optimization (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Downhole and wellsite flow metering (1.00)
- (2 more...)
...NAUTILUS A NEW TECHNOLOGY FOR SUBSEA PRODUCTION: DEVELOPMENT AND ...TEST RESULTS J. N. Renault, Total, Paris La Dgense, France Abstract. NAUTILUS is a subsea 1.3 MW electri...n hydrocarbon multiphase loop. This new technology available to-day can play a key role in offshore production due to the economical impact on deep water and satellite field developments; it can also substantia...
... up, planned and emergency shutdown, turndown - A power supply system and power control up to in production, etc. 130 km (frequency converter, step up transformer, - To meet environmental and safety requi...
...volving reservoir characteristics of an helico-axial impeller and a stationary diffuser. during the production life of the field. An important feature of this concept is its inherent This type of pump has demon...
Abstract. NAUTILUS is a subsea 1.3 MW electrical multiphase pumping unit which operates an helicoaxial multiphase pump with a high speed, directly coupled induction motor fed from an offshore platform mounted voltage inverter through a submarine three phase cable. The system operability and reliability demonstration up to 50 km was carried out under submerged conditions on an hydrocarbon multiphase loop. This new technology available to-day can play a key role in offshore production due to the economical impact on deep water and satellite field developments; it can also substantially increase the potential of exploitable reserves. This paper will present the technical results of the development and the advantages of this technology in subsea fields development. INTRODUCTION A subsea boosting system can grant access to marginal or satellite offshore fields. This is especially the a satellite well located within 50 km from its case when a deep water production support on site is not cost effective when compared to direct export to ‘mother’ production platform. a shallow water platform or directly to shore. Typical reservoir parameters for the application of a NAUTILUS multiphase booster station are indicated below: OBJECTIVE AND CHALLENGE NAUTILUS has been designed for installation on - Gas oil ratio (GOR) at standard conditions, 300 to - Gas liquid ratio (GLR) at pump suction, 2 to - Pump suction pressure, 150 to 725 psi - Pump discharge pressure, 725 to 1450 psi - Total flow at suction, 50 O00 to 200 O00 bbl/d Multiphase production represents an economically attractive solution when the wells are eruptive at the sea bottom: subsea multiphase pumping can significantly boost well productivity and substantially increase the potential of exploitable reserves. This is generally the case when the following reservoir and process conditions are met: - Lack of energy due to low GOR, - High water depth, - Long distance to final production facilities (high back pressure at the well-head), - Increasing or high water-cut. Used as an early production system, NAUTILUS can delay and/or facilitate the decision to implement a full development and reduce the time lag between the reservoir discovery and the first oil production. 1400 scft/bbl 12 vol/vol The objective of the NAUTILUS Project is to design, build and evaluate a subsea multiphase electric booster system to demonstrate its operability and reliability. The challenges were the development of a subsea multiphase boosting system for variable speed over long distances (50 km) and the development of key components required for the electrical power transmission with its associated control and communication system. THE NAUTILUS CONCEPT Boosted by a subsea helico-