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United Kingdom
This paper summarizes a three-year research on the overtrawlability of pipe-in-pipe, and develops the method to access it. Overtrawlablity is the ability of the pipe to resist the trawl gear impact and the pull-over force. The trawl gear will first impact the pipe and then pull over the pipe. If the overtrawlable capacity of the pipeline is insufficient, the trawl gear may damage the pipeline by denting or bending the pipe heavily. Overtrawlability of the pipeline has a direct bearing on whether the pipeline needs to be protected by burial with significant cost savings if burial is not required. DNV-RP-F111 and the other industry guidelines give a method to estimate the overtrawlability, but currently there is no method specifically for pipe-in-pipe. The outer pipe gives the inner pipe extra protection, and it does not have to resist internal pressure and can therefore accommodate a greater level of indentation than a single-wall pressure-containing pipe. If we apply the approach for the single wall pipe to pipe-in-pipe, the results are likely to be conservative. Therefore, an assessment of the overtrawlability of pipe-in-pipe is necessary to be conducted before making any trenching decisions, and to avoid providing unnecessary protection. With this motivation, a three-year JIP has been conducted at the National University of Singapore to better understand the overtrawlability of pipe-in-pipe, and to find the method to assess it. The research includes three different experiment programs to investigate the impact and pull-over responses. FE models of indentation and impact are developed and validated against first-hand experimental data. A new relationship of load-deflection relationship is developed to assess the impact response. External pressure is considered by the FE model using hydrostatic fluid element. Small scale pull-over experiments are conducted to study the pull-over force for different pipes and different conditions. The research work altogether develops the way to analysis the response of pipe-in-pipe when it interacts with a trawl gear. Finally, A comparison between a pipe-in-pipe and a single wall pipe shows the difference between them and throws light on the issue of trenching for pipe-in-pipes to some extent.
- Europe > United Kingdom > North Sea (0.89)
- Europe > Norway > Norwegian Sea (0.89)
- Europe > Norway > North Sea (0.89)
- (2 more...)
Maintaining effective cathodic protection for offshore facilities poses a challenging task for operators with ageing assets. Cathodic protection can be characterised by the reduction of the corrosion rate on metal surfaces that are continuously exposed to seawater and sediments via electrochemical protection. Integrity management of these cathodic protection systems is vital as facilities begin to reach their intended design life and operators look for life extension options. An oil field consisting of a number of well head platforms, a living quarter platform, a flare platform and a processing platform were required to be re-qualified and investigated for possible life extension measures. The cathodic protection assessment for these platforms is the focus of this paper, where the assessment process was critical in assuring the long term integrity. To guarantee the integrity of the facilities, a methodology that incorporated initial calculations based on mass and current requirements in conjunction with calibration calculations, factoring in present conditions of the facilities, were developed to predict the integrity of the systems for re-qualification and life extension. This paper documents the initial cathodic protection assessment methodology as well as the calibration methodology used to assess each facility for re-qualification and life extension. The calibration calculations were developed to verify the cathodic protection based on measured /observed values rather than assumed design values recommended in the relevant standards and used in the initial cathodic protection calculations. The paper also provides an overview of the cathodic protection assessment for these offshore facilities in relation to the integrity management for life extension and mitigation options. This overview details the finding in regards to developing a successful cathodic protection program that can be managed and evaluated accurately to allow for prolonged design lives for offshore facilities.
- Europe (0.69)
- South America > Brazil (0.46)
- Asia (0.46)
- North America > United States (0.28)
- Overview (0.68)
- Research Report > New Finding (0.46)
- North America > Cuba > Gulf of Mexico (0.89)
- Europe > United Kingdom > North Sea (0.89)
- Europe > Norway > North Sea (0.89)
- (2 more...)
This paper presents the experiments and studies conducted on pipes for the assessment of Middle East to India Deepwater Pipeline (MEIDP) requirement. The MEIDP will be located in water depths up to 3500 m and consequently be subjected to very high external pressures which make the pipe collapse strength a major consideration for the project. The pipes of size 660.4 mm (26") OD × 37.1 mm WT and SAWL485 FDU manufactured by JCOE process were used for external pressure ring collapse testing in as-fabricated (AF) and thermal aged (HT) conditions. The simulation of ring collapse pressure using Finite Element Analysis (FEA) was also studied. The ring pressure collapse test results consistently demonstrated the advantage of heat soaked treatment at 3LPP coating temperature for enhanced external collapse pressure as compared to the as-fabricated pipes. The strain gauges and deflection sensors were used to measure the external collapse pressure by ring method. The test results were compared with the values predicted by Linear-Elastic Thick Wall theory considering the plain strain behaviour and ABAQUS for Non-Linear Finite Element analysis to simulate the collapse pressure. A comparative study of ring collapse pressure testing, FE analyzed collapse pressure and DNV calculated collapse pressure is also presented along with tensile and compression behaviour of pipe material.
- Research Report > New Finding (0.40)
- Research Report > Experimental Study (0.40)
- Europe > United Kingdom > North Sea > Northern North Sea > West-Central Viking Graben > Scottish Area Gas Evacuation (SAGE) System (0.99)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > Scottish Area Gas Evacuation (SAGE) System (0.99)
Active heating of subsea flowlines is an attractive solution for facing flow assurance issues related to always going deeper and longer, as well as more complex fluids and critical wellhead flowing conditions (pressure, temperature, flowrate) prone to pour point issues, hydrates and/or wax appearance risk. Over the last 15 years, several active heating technologies have been developed and operated in order to significantly help solve flow assurance issues from the subsea wellheads up to the surface support facilities. These technologies have demonstrated to be very different in their design and operability (use of hot water, direct or indirect electrical heating) but also in their efficiency and cost. In parallel with the development of heated flexible pipe designated IPB (Integrated Production Bundle) already used for field development in West Africa and Brazil as well as a rigid heated pipe-in-pipe technology, both using electrical heat trace cables, Technip has been involved in the design, construction and installation on several projects of all active heating technologies. Based on this extensive knowledge and track-record, this paper describes and compares the working principle as well as the advantages and drawbacks of the different active heating technologies. This paper also identifies their limitations with regards to field application, i.e. length and water depth based on their actual development status. On the basis of different generic case studies (shallow long tie-back, shallow in-field development, deep water tie-back and ultra-deep water in-field development), this paper finally reviews all the potential benefits the different active heating technologies can bring to a project and includes an economical comparison of these technologies.
- South America > Brazil (0.34)
- North America > United States (0.28)
- Europe > Norway (0.28)
- Africa > West Africa (0.24)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > PL 043 DS > Block 3/15 > Alwyn Area > Islay Field > Brent Formation (0.99)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > PL 043 DS > Block 29/6c > Alwyn Area > Islay Field > Brent Formation (0.99)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > PL 043 DS > Block 26a > Alwyn Area > Islay Field > Brent Formation (0.99)
- (4 more...)
A Coiled Tubing Perforating Solution Incorporating a Gun Deployment System and Dynamic Underbalance Technique Improves Well Production in High Angle Deep Gas Wells in Saudi Arabia
Al Jubran, Hasan Hussain (Saudi Aramco) | Leal, Jairo (Saudi Aramco) | Al BuHassan, Shaker (Saudi Aramco) | Bolarinwa, Simeon (Saudi Aramco) | Kharrat, Wassim (Saudi Aramco) | Pulson, Dave (Saudi Aramco) | Barnawi, Mazen (Saudi Aramco)
SaudiAramco has recently initiated a change in gas well design in the Ghawar fieldof Saudi Arabia. The new approach is to drill deviated cased hole gas wellsthrough the reservoir to increase the length of contact of the productive zoneand thereby s wells were drilled as avertical cased hole through the reservoir or open hole horizontal gas wells. Theincreased well deviations, measured depths and resultant increase in reservoirsections required a new approach to the perforating solution for these wells toconnect them to the gas plants. Various techniques were reviewed, consideringsafety, operating efficiency and well performance. The final solution was todeploy the perforating systems on electric coiled tubing (CT) and run all theguns in one run using completion insertion and retrieval under pressure (CIRP) asa deployment system, which allowed the guns to be run and pulled under livewell conditions without having to kill the well. Thispaper details the learning curve and lessons learned of the implementation ofthis technique in five gas wells. The deployment system and pressure controlequipment were optimized to satisfy Saudi Aramco's requirement for threebarriers. A CT cleanout run was added before perforation to remove any debrisfrom the wellbore causing a problem to the depth correlation tools. An existingmCT tower was used to support the very long wellhead stack, but due to its height limitation a special solution was implemented to enable safe CToperations. A deployment system under live well conditions was used to minimizeCT runs, operating time and cost savings. The static underbalance condition was set before running the guns, combined with the dynamic underbalance perforatingtechnique and deep penetrating charge gun design were implemented to optimizethe well performance. This technique allowed safe and efficient perforating in a single underbalance run of these five gas wells. Thepaper also covers the planning of the perforating solution, Health, Safetyand Environment (HSE) considerations, equipmentselection, operational procedures, job execution and results
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.56)
- Europe > United Kingdom > North Sea > North Sea > Northern North Sea > South Viking Graben > Block 16/28 > Andrew Field (0.99)
- Europe > United Kingdom > North Sea > North Sea > Northern North Sea > South Viking Graben > Block 16/27a > Andrew Field (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Northern North Sea > South Viking Graben > Block 16/28 > Andrew Field (0.99)
- (9 more...)
Feasibility of the Steam-Assisted-Gravity-Drainage Process in Offshore Heavy Oil Reservoirs with Bottom Water
Dong, Xiaohu (China University of Petroleum, Beijing) | Liu, Huiqing (China University of Petroleum, Beijing) | Zhang, Zhaoxiang (China University of Petroleum, Beijing) | Lu, Chuan (China University of Petroleum, Beijing) | Fang, Xin (China University of Petroleum, Beijing) | Zhang, Gaige (China University of Petroleum, Beijing)
Due to the water-coning problem, cycle steam stimulation (CSS) in the heavy oil reservoirs with bottom water is often less effective, and the oil recovery is even below 10%. Steam assisted gravity drainage (SAGD) is the oil-producing process with a constant pressure-drop (about 0.30 MPa), and it is a potential technique for this reservoirs. Through the implementation of SAGD, bottom water could be effectively controlled. Aiming at the heavy oil block of LD5-2N in Bohai offshore oilfield, the SAGD performance in heterogeneous heavy oil reservoir with bottom water was numerically studied in this paper. In these simulation models, the water was broken into three components (connate water, injected water and bottom water) to study the water producing in SAGD process. Thus, the influences of startup approach, oillayer thickness, water thickness and the distance between well-pair and bottom-water on the water rising were all simulated. Thereafter, a set of numerical simulations were performed to assess the shale issues in SAGD process, e.g. the vertical and horizontal position of shale-barriers, the shale distribution range, the barrier permeable condition and the macroscopic vertical permeability. Results indicated that bottom water reduced the ultimate recovery of SAGD process by about 10%~20% of the OOIP. The startup by steam-circulation was much suitable for the bottom water heavy oil reservoir instead of CSS approach. The bottom water tremendously reduced the startup pressure-decline rate, and thus the startup-time was prolonged. The distance between well pair and water zone had a great influence on the SAGD performance, and a small distance would delay the beginning time of the steam-chamber rising. For reservoir heterogeneity, the vertical and horizontal heterogeneity have great influence on the drainage process, especially the shale cases. It tremendously decreased the recovery rate by about one time. This investigation could be used as a tool for the successful design of SAGD process in heavy oil reservoirs with bottom water.
- North America > United States (1.00)
- Europe (1.00)
- Asia (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (1.00)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > Block 3/28a > Bressay Field (0.99)
- Asia > China > Liaoning > Bohai Basin > Liaohe Basin > Liaohe Field (0.99)
Copyright 2014, Offshore Technology Conference This paper was prepared for presentation at the Offshore Technology Conference Asia held in Kuala Lumpur, Malaysia, 25-28 March 2014. This paper was selected for presentation by an OTC program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Offshore Technology Conference and are subject to correction by the author(s). The material does not necessarily reflect any position of the Offshore Technology Conference, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Offshore Technology Conference is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of OTC copyright. Abstract The use of dope-free tubulars in offshore operations has been increasingly adopted by different operators since its debut in the North Sea in 2003. Dope-free tubulars replace the storage and running pipe dope historically used in casing and tubing by a dry coating applied on pipe threads in an industrial controlled environment. The elimination of dope greatly simplifies the supply chain process involved in preparing casing and tubing for offshore wells, thus increasing efficiency and safety, and lessening the environmental impact of the process. The main benefits of this technology are: improved operational efficiency - preparation, running, pulling, management of rig returns; reliability: connections are made up in a more consistent and repetitive manner as the coating is applied as part of an industrial process replacing a manual operation; improved well productivity: eliminating the damage to the formation created by the pipe dope; and reduced impact on Health, Safety & Environment.
- Europe > Norway > North Sea (0.49)
- Asia > Malaysia > Kuala Lumpur > Kuala Lumpur (0.24)
- North America > Canada > Newfoundland and Labrador > Newfoundland > North Atlantic Ocean > Atlantic Margin Basin > Grand Banks Basin > Jeanne d'Arc Basin (0.99)
- Europe > Norway > North Sea > Central North Sea > Central Graben > PL 018 > Block 2/4 > Greater Ekofisk Field > Ekofisk Field > Tor Formation (0.99)
- Europe > Norway > North Sea > Central North Sea > Central Graben > PL 018 > Block 2/4 > Greater Ekofisk Field > Ekofisk Field > Ekofisk Formation (0.99)
- (74 more...)
Copyright 2014, Offshore Technology Conference This paper was prepared for presentation at the Offshore Technology Conference Asia held in Kuala Lumpur, Malaysia, 25-28 March 2014. This paper was selected for presentation by an OTC program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Offshore Technology Conference and are subject to correction by the author(s). The material does not necessarily reflect any position of the Offshore Technology Conference, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Offshore Technology Conference is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of OTC copyright. Abstract Burial of submarine pipelines and cables is common practice in the North Sea where potentially damaging threats such as fishing gear interaction and dragged anchors are high, or where burial is required for flow assurance. Whilst the requirement to bury pipelines in Asia-Pacific has not had the same imperative as in the North Sea, there is now a growing requirement for pipelines to be trenched, particularly to increase mechanical protection and improve on-bottom stability. Trenching is considered to be one of the offshore activities that carry most commercial risk. It is therefore important to ensure that the correct tool is selected for the anticipated field conditions and to establish realistic performance criteria based on regional experience in the prevailing seabed soils. This paper compares the primary differences between seabed sediments of the North Sea to those that prevail in Asia-Pacific and discusses where differences in these conditions can affect the choice of burial equipment and tool performance when planning trenching in this region. Performance benchmarks for most trenching systems are based on experience and empirical relationships developed for seabed soils typically found in more northern latitudes. Consequently, the main body of burial performance data does not account for the carbonate rich seabed sediments for example that are prevalent in the Asia-Pacific region. Carbonate cemented soils and weak rocks pose a significant challenge to burial and trenching experience in these materials remains very limited.
- Oceania > Australia (0.95)
- Europe > North Sea (0.76)
- Europe > United Kingdom > North Sea (0.66)
- (4 more...)
- Geology > Rock Type > Sedimentary Rock (0.94)
- Geology > Sedimentary Geology > Depositional Environment > Marine Environment (0.93)
- Oceania > Timor-Leste > Timor Sea > Bonaparte Basin (0.99)
- Oceania > Australia > Timor Sea > Bonaparte Basin (0.99)
- Asia > China > Hainan > Yinggehai Basin > Ledong Field (0.99)
- (12 more...)
The goal of Subsurface Containment Assurance (SCA) is to ensure that no adverse environmental impact, damage to operated assets, or impacts on well operations (drilling or production) occur due to leakage of production or injection fluids from reservoir intervals. Subsurface Containment Assurance involves the integrated efforts of subsurface (reservoir and overburden characterization), wells (planning, construction, well integrity and abandonment), operations (process safety and well operations and management of change) and HSE (health, safety and environment) teams. Disciplines must act together to develop and implement a surveillance plan to proactively monitor containment during well and injection operations in offshore fields. The paper will describe the elements of a Subsurface Containment Assurance Program (SCAP) that are required for business units operating offshore across the entire life cycle from exploration to mature developments. The program is designed to be comprehensive, yet flexible; and focuses on the critical elements and risks for individual operating units. A consistent framework needs to be created and implemented that draws from existing tools for reservoir and overburden characterization and field management, and combines these tools to reduce the risk of unintended subsurface fluid containment loss. Specific assessment criteria and ranking approaches and tools for qualitative and quantitative estimation of containment risks will be discussed. Finally, surveillance programs focusing on containment using both direct and indirect measurements will be highlighted with a focus on offshore data gathering. Loss of containment puts the environment, operating equipment and personnel at risk. Proactively identifying and mitigating containment risks is critical to operate safely. Containment assurance, particularly offshore, needs to be a key element of any asset and subsurface management plans.
- Asia > Middle East (1.00)
- Africa (1.00)
- North America > United States > Texas (0.69)
- (2 more...)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Structural Geology > Fault (0.68)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (0.68)
- (4 more...)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Area do 1-RJS-366 > Frade Block > Frade Field (0.99)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Mississippi Canyon > Block 854 > Ursa Field (0.99)
- (31 more...)
- Information Technology > Communications (0.46)
- Information Technology > Security & Privacy (0.34)
High pressure/high temperature (HP/HT) pipelines are potentially susceptible to global buckling which can result in failure unless properly managed. Traditionally global buckling has been prevented from occurring by restraining the pipeline; however an alternative solution is to control the high effective force that occurs in the system by providing a planned buckle initiation scheme. Design guidelines and standards such as SAFEBUCK offer comprehensive guidance to design for global buckling. However, the current industry approach does not account for areas of high seabed mobility where effective frictional restraint can vary significantly along a pipeline route, over a short distance. The effect of this phenomenon on global buckling design is discussed in this paper and a refined design approach presented. The conventional method is to perform global buckling design considering lower bound friction to assess the propensity for buckling and upper bound friction to assess the post buckle response. This approach is sufficient when considering a conventional range of possible frictional restraint – i.e. in the North Sea / Arabian Gulf. However, in areas of high sediment mobility e.g. NWS Aus. a much wider range of soil restraint may occur as a result of spanning and burial of pipelines created by the mobile seabed. Utilising the standard approach may result in very conservative design, for instance with the requirement to restrain the pipeline rather than control global buckling. This paper presents a more refined approach by taking the existing soil restraint and assessing if global buckling can still occur, in this manner the upper bound friction is refined to a lower value at which a global buckle can feasibly initiate. Reducing the frictional restraint range allows a controlled buckling scheme to become feasible and a more cost effective design to be adopted.