Development of a Subsea Wireline Winch System
- J.A. Graser (Somus Well Services)
- Document ID
- Society of Petroleum Engineers
- SPE Production Engineering
- Publication Date
- August 1987
- Document Type
- Journal Paper
- 218 - 222
- 1987. Society of Petroleum Engineers
- 5.1.2 Faults and Fracture Characterisation, 1.7.5 Well Control, 4.2 Pipelines, Flowlines and Risers, 4.5.10 Remotely Operated Vehicles, 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc), 4.2.4 Risers, 7.2.3 Decision-making Processes, 4.5.7 Controls and Umbilicals, 1.10 Drilling Equipment, 4.2.3 Materials and Corrosion, 4.3.4 Scale, 3 Production and Well Operations, 1.7 Pressure Management, 2 Well completion
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This paper describes a subsea wireline winch system designed to work over subsea well completions from a dynamically positioned work vessel in North Sea conditions. The system is compared with other options, and applications for each type are suggested. Results of a land test of the prototype are described. prototype are described. History
During the past 10 years, the number of subsea well completions has rapidly increased. Mohr reports 167 active subsea completions worldwide and predicts that another 423 completions are likely for currently identified fields, with another 525 installations for unannounced and/or undiscovered fields within the next 10 years. Since 1984, the change in the price of crude may have invalidated his predictions. There may be more, rather than fewer, wells predictions. There may be more, rather than fewer, wells completed subsea.
Oil companies are considering a number of methods of operating subsea well completions. These range from the Hamilton Bros. Oil and Gas Ltd.'s Argyll system of scattered straight holes to Shell U.K. E and P's underwater manifold center (UMC) with template wells, directional holes, and through-flowline (TFL) servicing. Most new projects favor template wells and wireline servicing projects favor template wells and wireline servicing similar to North Sea Sun Oil Co. Ltd.'s Balmoral field. Variations of Sun's solution include more or fewer remote satellite wells. The relative costs for developing a typical North Sea marginal field would be on the order of $150 million for Hamilton's solution, $300 million for Sun's solution, and more than $500 million for Shell's UMC solution. The main disadvantage of Hamilton's system of remote, scattered, straight subsea holes is the high maintenance cost of the wells and flowlines themselves. This maintenance would include downhole safety valve (DHSV) replacement and reservoir data gathering, If a low-cost method of wireline-servicing remote subsea wells could be developed, it would make Hamilton's low-capital-cost solution much more attractive.
During the last 10 years, there has been a gradual rise in the number of subsea completions in the North Sea. Phillips Petroleum Co. Norway at Ekofisk first used Phillips Petroleum Co. Norway at Ekofisk first used subsea completions to bring their exploratory wells on early production. This was followed by Hamilton at Argyll, BP production. This was followed by Hamilton at Argyll, BP Petroleum Development Ltd. at Buchan, Shell at Petroleum Development Ltd. at Buchan, Shell at Cormorant, Hamilton at Duncan, Sun at Balmoral, and Texaco North Sea U.K. Co. at Highlander. Other operators have satellite injection or production wells. There are now more than 50 subsea well completions in the North Sea, with more planned.
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