Yme Marginal Field, 12 km Subsea Gas Lift Experience

Øverland, Alf M.; Ramstad, Helge J.

doi:10.2118/71539-ms

Cited by 6 publications

(1 citation statement)

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“…These systems are now being deployed in ways rarely encountered in previous development schemes. 1,2,3 One of the forces driving increased use of subsea production systems is the dramatic reduction in development costs when compared with conventional methods. 4 In many cases, the use of a subsea tieback is the only viable option to develop these resources.…”

Section: Introductionmentioning

confidence: 99%

An Assessment of Subsea Production Systems

Devegowda

Scott

2003

Proceedings of SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe rapidly accelerating shift to subsea production systems represents a significant departure from conventional operations. Historically, subsea wells have had a good track record. However, complex subsea systems are now being deployed in ways rarely encountered in previous development schemes.These increasingly complex systems present a number of technical challenges. This paper presents an assessment of subsea production systems, considering the technical, operations and safety issues associated with this development modality.This assessment considers the following general areas: 1) subsea processing; 2) flow assurance; 3) long-term well monitoring and, 4) safety & environmental concerns. A review of the state-of-the-art in each of these areas is presented and several technical and operational gaps are identified. One of the most striking findings is the low ultimate recovery anticipated from many subsea wells. Two new technologies that can have a positive impact on recoveries are subsea multiphase pumping and subsea separation/processing. This assessment found, however, that the safety systems seem to be absent from current subsea processing plans. Other concerns include the inability to monitor subsea wells for sustained casing pressure, a widespread problem in the GOM.With regard to flow assurance, much work has been done to develop design tools for flow assurance, little has been done in the area of monitoring subsea production systems to detect and locate these materials. As more subsea systems are placed in operation, the monitoring and operation needs (rather than the design needs) will likely emerge as the top priority.

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Section: Introductionmentioning

confidence: 99%

An Assessment of Subsea Production Systems

Devegowda

Scott

2003

Proceedings of SPE Annual Technical Conference and Exhibition

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The Virtual Well: Guidelines for the Application of Dynamic Simulation to Optimize Well Operations, Life Cycle Design, and Production

Mantecon¹

2007

All Days

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The rapid uptake of transient multiphase flow simulation of wells demonstrates the recognised value to the Industry of this relatively new technique. In offshore, subsea and deepwater well locations, and in long horizontal, multi-layer, multi-lateral, big-bore and complex well completions, Industry can benefit from dynamic simulation for sound engineering design, and optimisation of costs and production. Dynamic simulation provides the possibility of building a virtual well that can be used to analyse "what if" case scenarios and predict specific results. It is an excellent tool to understand transient well behaviour and determine the optimum process to eliminate or minimise potential transient problems. It does not replace NODAL® analysis but fills a gap where NODAL® analysis techniques cannot provide solutions. Once the dynamic well model is validated it can also be used as an implicit gauge and/or a virtual DTS during production/injection operations. This paper details some applications, and provides guidelines for the proper use of dynamic simulation in key areas including: well clean-up, well kick-off, watercut limit, flow stability, flow assurance (hydrates), gas lift requirements, large tubing ID flow, production optimisation, and well test equipment sizing. Well Dynamic Simulation is a useful tool that can be used during FEED and at any stage of the well life cycle to "virtually" run through a complete case scenario and predict the well multi-phase flow behaviour (including trends and profiles of liquid hold-up, pressure and temperature), providing valuable information to optimise technical, operational and HSE integrity during design and operation of production systems. Introduction Dynamic simulation is a proven tool applied for years by facilities engineers for pipeline and slugcatcher designs. The application of multiphase flow transient simulation in wells is a new practice which requires different understanding and expertise. Multi-discipline teams or cross-discipline experience is required to properly build and integrate the well model into the total production system model. The development of offshore, subsea, and deepwater fields and the use of more sophisticated drilling techniques and well completions require greater understanding of the transient pressures, temperatures and liquid hold-up. The high capital and operating costs, clearly merit detailed dynamic analysis of wells and associated production systems. Currently, there are no best practice standards for the application of dynamic simulation to wells. The main objective of this paper is, therefore, to create awareness and present some guidelines to facilitate the application of this technique in order to optimise well integrity, well operations, well life cycle design and production. Firstly, the dynamic simulation techniques are compared with traditional steady state NODAL® analysis techniques to define the areas of application. Secondly, the main well dynamic applications (using "predictive" and "matching" approaches) are discussed and examples of relevant cases are provided. The results of which provide the confidence to use dynamic simulation in design and operations to minimise risk, uncertainty, safety hazards and environmental impact and optimise CAPEX-OPEX and production. The dynamic simulation work covered in this paper was performed using the multiphase flow transient numerical simulator OLGA.

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Use of Dynamic Simulation To Assist Commissioning and Operating a 65-km-Subsea-Tieback Gas Lift System

Salman

Wittfeld

Lee

et al. 2009

SPE Production &Amp; Operations

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Summary The Penguins field comprises of a cluster of reservoirs in the northern North Sea. The need for gas lift was foreseen during the early stages of field-development planning. Five oil wells were completed for gas lift service. A 65-km 4-in. gas lift line was laid in 2006, running alongside the production line and tied into the drill centers by flexible 2-in. jumpers. Because of the unconventionally long distance of the field from the platform, it was necessary to carry out transient modeling of the full commissioning and gas lift startup process. Particular attention was required, both in design and operating procedure, to avoid hydrates and excessive velocities in the high-pressure, low-temperature system. Dynamic simulation with the industry-renowned transient software package (OLGA v5.1 2006) has proved to be valuable for the commissioning of this gas lift system. It also explained discrepancies between anticipated behavior of the shear orifice valve and the actual behavior seen in the field. The overall project outcome was a success, with excellent improvements in field stability and production. The project was justified on the basis of kickoff capability only, but continuous gas lift is required to maintain stable flow from all of the wells.

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Yme Marginal Field, 12 km Subsea Gas Lift Experience

Cited by 6 publications

References 0 publications

An Assessment of Subsea Production Systems

An Assessment of Subsea Production Systems

The Virtual Well: Guidelines for the Application of Dynamic Simulation to Optimize Well Operations, Life Cycle Design, and Production

Use of Dynamic Simulation To Assist Commissioning and Operating a 65-km-Subsea-Tieback Gas Lift System

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