Gravity-Fed Riserless Coiled Tubing Operations in Ultra-Deepwater: A Milestone Achievement for Riserless Intervention and Plug and Abandonment

2021 ◽  
Author(s):  
Andrea Sbordone ◽  
Bernt Gramstad ◽  
Per Buset ◽  
Rafael Rossi ◽  
Charlie Tramier ◽  
...  
Keyword(s):  
Deep Water ◽  
Oil And Gas ◽  
Open Water ◽  
Oil And Gas Industry ◽  
Gas Industry ◽  
Norwegian Sea ◽  
Improve Efficiency ◽  
Coiled Tubing ◽  
First Time ◽  
Water Depths

Abstract In a continuous effort to reduce cost and improve efficiency, the Oil and Gas industry has been trying for the last 10 years to develop methods to perform subsea Coiled Tubing (CT) operations from a vessel and without a riser. In September 2020 a large campaign of Riserless Coiled Tubing (RLCT) coring was successfully executed in the Norwegian Sea, on the Mohns Ridge, approximately 330 nautical miles from the coast. The campaign was performed from a small Anchor Handler Tug Supply vessel, the Island Valiant. A total of 14 open water gravity-fed RLCT runs were executed in water depths between 2780 and 3085 m. The system performed extremely well and proved to be very robust, efficient and effective for these innovative operations. This was the first time that RLCT coring operations were completed without the use of a subsea injector, in the so-called gravity-fed mode, and in such ultra-deep water. This paper describes the project in detail, including the system setup used, a summary of the operations and the actual results achieved, before discussing future improvements and applications of the RLCT technology.

Tubarão Martelo Field Riser System: Shallow Water Challenging

2015 ◽  
Author(s):  
Elton J. B. Ribeiro ◽  
Zhimin Tan ◽  
Yucheng Hou ◽  
Yanqiu Zhang ◽  
Andre Iwane
Keyword(s):  
Shallow Water ◽  
Deep Water ◽  
Oil And Gas ◽  
Vertical Motion ◽  
Oil And Gas Industry ◽  
System Configuration ◽  
Wave Load ◽  
Gas Industry ◽  
Campos Basin ◽  
Water Problem

Currently the oil and gas industry is focusing on challenging deep water projects, particularly in Campos Basin located coast off Brazil. However, there are a lot of prolific reservoirs located in shallow water, which need to be developed and they are located in area very far from the coast, where there aren’t pipelines facilities to export oil production, in this case is necessary to use a floating production unit able to storage produced oil, such as a FPSO. So, the riser system configuration should be able to absorb FPSO’s dynamic response due to wave load and avoid damage at touch down zone, in this case is recommended to use compliant riser configuration, such as Lazy Wave, Tethered Wave or Lazy S. In addition to, the proposed FPSO for Tubarão Martelo development is a type VLCC (Very Large Crude Carrier) using external turret moored system, which cause large vertical motion at riser connection and it presents large static offset. Also are expected to install 26 risers and umbilicals hanging off on the turret, this large number of risers and umbilicals has driven the main concerns to clashing and clearance requirement since Lazy-S configuration was adopted. In this paper, some numerical model details and recommendations will be presented, which became a feasible challenging risers system in shallow water. For instance, to solve clashing problem it is strictly recommended for modeling MWA (Mid Water Arch) gutter and bend stiffener at top I-tube interface, this recommendation doesn’t matter in deep water, but for shallow water problem is very important. Also is important to use ballast modules in order to solve clashing problems.

New Well Intervention Means as an Answer to Offshore Minimalist Platform Concept: A Breakthrough from Mahakam, Indonesia

2021 ◽  
Author(s):  
Risal Rahman ◽  
Reyhan Hidayat ◽  
Pratika Siamsyah Kurniawati ◽  
Rantoe Marindha ◽  
Gerardus Putra Pancawisna ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Cost Optimization ◽  
Oil And Gas Industry ◽  
Project Planning ◽  
Gas Industry ◽  
Safety Issues ◽  
Coiled Tubing ◽  
Remote Operation ◽  
Innovation And Technology ◽  
Hazardous Zone

Abstract Nowadays oil and gas industry are encouraging the independents and majors to take a fresh look at the technology and concepts required to develop marginal shallow water fields using a minimal platform approach. Innovation on well intervention means (lighter, smaller and less footprint) that fit for Offshore Minimalist Platform (OMP) is needed, including optimizing time and cost during well intervention activities in OMP. To achieve the objectives, well intervention innovation and technology are the main focuses. Intervention activities commonly done on campaign basis with several units (slickline, wireline, coiled tubing, testing) shall be integrated in a safe manner. The approach of integration shall signify these points:Identifying potential jobs in OMP to be done by well intervention methodsIdentifying necessary well intervention means and methods to support the jobs (combo unit, micro coil, hazardous zone redefinition, remote operation)Creating project planning and schedulingPerforming site visit and risk assessmentImplementation and operational executionEvaluation of overall project execution result The following results were obtained after the integration performed:No major safety issues during operationExemplary method and risk assessment for well intervention activities which can be applied for next campaignsTrials on well intervention new units and method (combo unit, micro coil, hazardous zone redefinition, remote operation), were safely performed with some optimization100% success ratio60% on supply boat arrangement35% efficiency in N2 consumption for CT operation45% efficiency in diesel consumption20% - 40% efficiency in Rig Up Time28% less in Job Cost compared to conventional unit These innovations are proven as reliable method to answer OMP challenges with main advantages on footprint and cost optimization. Through this paper, we would like to share lucrative well intervention breakthrough and innovation in OMP with measurable milestones.

Dynamic Analysis of a Semisubmersible-type Bucket Ladder Dredge

1999 ◽  
Vol 36 (03) ◽  
pp. 143-156
Author(s):  
_ Arcandra ◽  
Robert E. Randall ◽  
Moo H. Kim
Keyword(s):  
Dynamic Analysis ◽  
Oil And Gas ◽  
Response Spectra ◽  
Oil And Gas Industry ◽  
Wave Forces ◽  
Diffraction Radiation ◽  
Gas Industry ◽  
Tin Deposits ◽  
Response Amplitude Operators ◽  
Water Depths

A semisubmersible-type bucket ladder dredge is a candidate to satisfy the need of the Indonesian tin mining company, PT Timah, to recover tin deposits in water depths of 50 m and deeper. Their current vessel is a barge-type bucket ladder dredge capable of operating in depths shallower than only 30 m. In order to evaluate the dredging capability in 50 m water depth, a dynamic analysis of both semisubmersible-type and barge-type bucket ladder dredges was conducted. The vessel was designed by modifying an existing semisubmersible platform used in the oil and gas industry, while the barge-type used is a conventional bucket ladder dredge. Hydrodynamic coefficients, wave forces, and response amplitude operators (RAOs) of both vessels were computed by using the 3D linear diffraction-radiation software WAMIT. The response spectra of the vessels were obtained in head, quarter, and beam seas of sea state 4. The effect of mooring stiffness was also investigated. Besides modeling the system with low stiffness, such as a catenary mooring, the dynamic analysis was also conducted for the free-floating condition. Finally, the motion performance for the two vessels was compared for various sea conditions, and it is shown that the semisubmersible-type bucket ladder dredge performs better with smaller responses in the selected sea conditions expected in water depths greater than 50 m.

Evolution of Completion Techniques in the Lower Shaunavon Tight Oil Play in Southwestern Saskatchewan

2015 ◽  
Author(s):  
D. J. Schlosser ◽  
M.. Johe ◽  
T.. Humphreys ◽  
C.. Lundberg ◽  
J. L. McNichol
Keyword(s):  
Oil And Gas ◽  
New Technology ◽  
Oil And Gas Industry ◽  
Field Trials ◽  
Gas Industry ◽  
Point Energy ◽  
Horizontal Drilling ◽  
Oil Reserves ◽  
Coiled Tubing ◽  
Open Hole

Abstract The Oil and Gas industry has explored and developed the Lower Shaunavon formation through vertical drilling and completion technology. In 2006, previously uneconomic oil reserves in the Lower Shaunavon were unlocked through horizontal drilling and completions technologies. This success is similar to the developments seen in many other formations within the Williston Basin and Western Canadian Sedimentary Basin including Crescent Point Energy's Viewfield Bakken play in southeast Saskatchewan. In the Lower Shaunavon play, the horizontal multistage completion era began in 2006, with horizontal divisions of four to six completion stages per well that utilized ball-drop sleeves and open-hole packers. By 2010, the stage count capabilities of ball-drop systems had increased and liners with nine to 16 stages per well were being run. With an acquisition in 2009, Crescent Point Energy began operating in the Lower Shaunavon area. The acquisition was part of the company's strategy to acquire large oil-in-place resource plays. Recognizing the importance that technology brings to these plays, Crescent Point Energy has continuously developed and implemented new technology. In 2009, realizing the success of coiled tubing fractured cemented liners in the southeast Saskatchewan Viewfield Bakken play, Crescent Point Energy trialed their first cemented liners in the Lower Shaunavon formation. At the same time, technology progressed with advancements in completion strategies that were focused on fracture fluids, fracture stages, tool development, pump rates, hydraulic horsepower, environmental impact, water management, and production. In 2013, another step change in technology saw the implementation of coiled tubing activated fracture sleeves in cemented liner completions. Based on field trials and well results in Q4 2013, Crescent Point Energy committed to a full cemented liner program in the Lower Shaunavon. This paper presents the evolution of Crescent Point Energy's Lower Shaunavon resource play of southwest Saskatchewan. The benefits of current completion techniques are: reductions in water use, increased production, competitive well costs, and retained wellbore functionality for potential re-fracture and waterflooding programs.

Cost Element Modelling, Prediction and Optimization in a Dual-Completion Well During a Coiled Tubing Unloading Operation

2021 ◽  
Author(s):  
Merit P. Ekeregbe
Keyword(s):  
Mathematical Model ◽  
Decision Making ◽  
Cost Estimation ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Correct Prediction ◽  
Reservoir Pressure ◽  
Gas Industry ◽  
Coiled Tubing ◽  
The Mathematical Model

Abstract In an era where cost is a significant component of decision making, every possibility of reducing operational cost in the Oil and Gas industry is a welcome development. The volatile nature of the Oil market creates uncertainty in the industry. One way to manage this uncertainty is by the ability to predict and optimize our operations to reduce all of our cost elements. When cost is planned and predicted as accurately as possible, the operation optimizations can be managed efficiently. Practically, all new drills require CT unloading of the completion or kill fluids to allow the natural flow of the wells. Hitherto, there is no mathematical model that combines information from one of the wells in an unloading dual completion project that can be used to aid decision-making in the other well for the same unloading project and thereby result in an effective cost-saving. Deploying the mathematical model of cost element prediction and optimization can minimize operational unloading costs. The two strings of the dual completion flow from different reservoirs. Still, the link between the two drainages post completion is the kill fluid density, and can aid in cost estimation for optimum benefit. The lesson learned or data acquired from the lifting of the slave reservoir string can be optimized to effectively and efficiently lift the master reservoir string. The decision of first unloading the slave reservoir string is critical for correct prediction and optimization of the ultimate cost. The mathematical model was able to predict the consumable cost elements such as the gallon of nitrogen and time that may be spent on the long string from the correlative analysis of the short string. The more energy is required for unloading the short string and it is the more critical well than the long string because it is the slave string since no consideration as such is given to it when beneficiating the kill fluid to target the long string reservoir pressure with a certain safety overbalance. The rule for the mud weight or the weight of the kill fluid is the highest depth with highest reservoir pressure which is the sand on the long string. With the data from the short string and upper sand reservoir, the lift depth and unloading operation can be optimized to save cost. The short string will incur the higher cost and as such should be lifted last and the optimization can be done with the factor of the LS.

New Generation of Heavy Wall Thicknesses Line Pipes for HPHT and Ultra-Deep Water Applications

2018 ◽  
Author(s):  
Stefano Crippa ◽  
Lorenzo Motta ◽  
Alessandro Paggi ◽  
Emanuele Paravicini Bagliani ◽  
Alessandro Elitropi ◽  
...  
Keyword(s):  
Wall Thickness ◽  
Deep Water ◽  
Oil And Gas ◽  
High Pressures ◽  
Oil And Gas Industry ◽  
Rolling Process ◽  
Corrosion Properties ◽  
Line Pipe ◽  
Gas Industry ◽  
New Generation

Oil and Gas industry in the last decades has increased the use and need of heavy wall thickness line pipes, in particular for onshore / offshore high pressures and high temperatures (HP/HT) and offshore deep water / ultra-deep water applications. The paper presents the results achieved by Tenaris on seamless line pipes in grades X65/X70, according to API 5L / ISO 3183, with wall thickness in a range from 40 to 60 mm and diameter between 6 5/8” and 16”, produced by hot rolling process followed by quenching and tempering. Such line pipes are able to withstand very demanding conditions, like sour environment, very high pressure and wide temperature range. In this publication, the main outcomes of laboratory testing activities on the mentioned materials will be presented as part of heavy wall line pipe qualification. For this purpose, a special testing program, including mechanical and corrosion tests, has been executed. Material demonstrated an excellent behaviour, exhibiting both mechanical, toughness and stress corrosion properties suitable for the envisaged harsh applications.

scholarly journals Colorado

2020 ◽  
Vol 6 (3) ◽  
Author(s):  
Ralph A. Cantafio
Keyword(s):  
Oil And Gas ◽  
General Trend ◽  
Oil And Gas Industry ◽  
Front Range ◽  
New Paradigm ◽  
Residential Housing ◽  
Oil And Gas Development ◽  
Gas Industry ◽  
Exclusive Jurisdiction ◽  
First Time

When Colorado Democratic Governor Jared Polis approved Senate Bill 181, this new law significantly redirected the historical focus of Colorado oil and gas regulation. This provided a significant delegation of land use related authority to local government for the first time since the passage of this Act in 1951. This new law moved away from the traditional notion of statewide regulation based upon exclusive jurisdiction by the Colorado Oil and Gas Conservation Commission (“COGCC”). While this change of legislative focus is significant, this latest direction is probably a natural continuation of a general trend that has been emerging in Colorado since certain Supreme Court Opinions were announced in 1992, as explained later in this Article. As the State of Colorado has, among other things, grown in population, residential housing now significantly finds itself competing with oil and gas development in the same geographical areas, especially the suburbs of the “Front Range.” Simultaneously, the political sentiment of Colorado has trended into a more significantly Democratic direction from a historically Republican majority. The law as to the governance of the oil and gas industry has now changed as a result of the passing of SB 181—from fostering the development of oil and gas industry to a new paradigm requiring the weighing of interests, including environmental concerns. This Article provides a historic explanation to allow the reader to better understand how this transition has come about. That which is observed in Colorado might also be seen as a potential harbinger of future change that could be noted in other oil and gas states.

Behavior Evaluation of Subsea Jumpers Exposed to Current by Experiment and FEM

2018 ◽  
Author(s):  
Mohammad Mobasheramini ◽  
Luciene Alves ◽  
Antonio Carlos Fernandes ◽  
Gilberto Bruno Ellwanger
Keyword(s):  
Deep Water ◽  
Oil And Gas ◽  
New Technologies ◽  
Flow Direction ◽  
Experimental Tests ◽  
Oil And Gas Industry ◽  
Experimental Result ◽  
Gas Industry ◽  
Oil Companies ◽  
Offshore Production

The oil and gas industry is headed toward deep water in recent years. Oil companies are seeking new technologies to meet the challenges of deep-water oil exploration and in the near future, this will bring new discoveries. The most difficulty of exploring oil in this region is the depth where the equipment is installed and the production lines must be safe for such activities. Full understanding of the dynamics of the behavior of this equipment is vital to the success of offshore production and operation due to environmental problems that can occur in an accident and a large amount of economic and human resources involved. The phenomenon of the vortex induced vibration (VIV) is complex and involves an interaction between hydrodynamic forces and the response of the structure. The force and displacement can be determined through experimental tests or the complete numerical simulation of the interaction between the structure and fluid. DNV-GL has recently published a guideline about the design of a subsea jumper [1], but it is still needed many studies and experiments to improve the evaluation of VIV in rigid subsea jumpers in the oil industry. The main objective of the present work is to investigate VIV phenomenon in a jumper exposed to uniform flow and verify its oscillation in the flow direction, which called inline VIV (VIVx). Throughout this study, the finite element method was used to perform the structural and modal analysis of the structure, in order to obtain the modes, frequencies and then validate the experimental result. Experimental analysis of jumpers was also performed in a current tank to evaluate the behavior of the jumper with the current flow.

Guyana: Liza Phase 1 Rapid Development in a Deepwater Frontier

2021 ◽  
Author(s):  
Amy Styslinger ◽  
David Yost ◽  
Gina Dickerson ◽  
Antoine Minois ◽  
Renee Wiwel
Keyword(s):  
Deep Water ◽  
Oil And Gas ◽  
Rapid Development ◽  
Phase 1 ◽  
Oil Production ◽  
Oil And Gas Industry ◽  
Development Project ◽  
Gas Industry ◽  
Cycle Times ◽  
Water Developments

Abstract The Liza Phase 1 development project, offshore Guyana, is an unique example of what the offshore oil and gas industry is capable of when working together to deliver a common objective. ExxonMobil and the Stabroek Block co-venturers, Hess Guyana Exploration Limited and CNOOC Petroleum Guyana Limited, commenced oil production from the Liza Destiny floating production, storage, and offloading (FPSO) vessel in December of 2019, less than 5 years from the initial discovery of hydrocarbons in the Staebroek block. With the production and export of its first barrels of oil, the project completed the establishment of a nascent oil and gas industry in Guyana that is poised for tremendous growth in the coming years. The Liza Phase 1 development consists of a 120 kbd conversion FPSO (The Liza Destiny) and a network of subsea infrastructure to produce from and inject in two drill centers. It is expected to develop a resource of about 450 MBO gross estimated ultimate recovery. The water depth ranges from 1,690–1,860 m throughout the development which is located approximately 200 km offshore Guyana. This paper highlights the scope and pace of the project and discusses three specific challenges overcome: the uncertainty of the metocean conditions, extending the application of the selected riser technology, and executing in a challenging and frontier offshore location. A key to the success of the project was the unified approach between stakeholders and the commitment to act as One Team. The Liza Phase 1 project rapidly developed a newly discovered deep water resource in a frontier location while overcoming numerous challenges. By delivering Guyana's first ever oil production among industry leading cycle times, the Liza Phase 1 project has set the foundation for the future of deep water developments in Guyana.

What To Expect When You’re Expecting Robots

2021 ◽  
Vol 73 (08) ◽  
pp. 22-29
Author(s):  
Trent Jacobs
Keyword(s):  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Permian Basin ◽  
Gas Industry ◽  
Norwegian Sea ◽  
New Class ◽  
Human Operators ◽  
The Right ◽  
Gas Supply

The market turmoil of 2020 left the upstream industry with diminished ranks, palpable concerns over long-term demand, and mounting pressure to reduce its carbon footprint. This made for what many consider a bullish case, as JPT has reported, for robotics uptake over the course of the decade. But there are reasons to temper expectations. After all, this is the oil and gas industry. The upstream land-scape is as vast as it is specialized. Each silo is a fortress of status quo to which robot developers must dedicate significant time and fortune in conquering. Some are worth the battle, especially in the offshore arena where factors of cost and safety have made this the most active corner of oil and gas robotics. Many other use cases may be worth bypassing. About 70% of the world’s oil and gas supply is produced onshore which, of course, is much more accessible to human operators. That means a robot dog in the Permian Basin has to jump over a much higher bar in order to create value than a robot dog tasked with inspecting a platform in the middle of the Norwegian Sea. Speaking of inspection, this is both the chief strength and upper limit for much of the current generation of robots. The next generation will be asked to fix things. And whatever they can’t do - or are just not the right tool for - look for it to be covered by industrial automation. As a new class of oil and gas robots finds its niche, and fights for investment dollars along the way, here are a few developments to track and points to consider. This Time It’s Different, Right Boss? The upstream sector pulled back from exploring the frontier of robotics and drone technologies in the last decade relative to other industries, but it is now being pulled forward by societal and technological shifts, according to Ed Tovar who runs an Austin-based consulting company, InTechSys, that serves the defense and energy industry.

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