Offshore Concept Summary

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1、Offshore Concept SummaryTopsidesThe topsides component covers processing facilities for oil or gas, including wellhead manifolding, separation, gas treatment, gas compression, condensate handling, export metering, water or gas injection, utilities, power generation, communications and control, quart

2、ers, drilling facilities, bulk materials and structural steel. Topsides: can range from a small well protector platform weighing a few hundred tonnes, to a large drilling platform including processing, compression and quarters and weighing more than 30,000 tonnes. The main process systems can be spe

3、cified together with the associated utilities, quarters and drilling and estimates equipment and bulk weights, material and fabrication costs, installation durations, design, management and HUC man-hours to produce an overall cost estimateJacketsThe Jacket component provides costs for jacket steelwo

4、rk and all appurtenances including piles, pile guides, anodes, conductor guides, riser guides, J tubes and lifting/installing aids. Jackets: traditional steel-piled jackets with three, four, six or eight legs can be selected based on the topsides weight, installation method and local environmental c

5、onditions. For topsides operating weights up to 1,600 tonnes and water depths up to 90m lightweight structures including guyed caissons, braced monotowers and lightweight jackets can be selected.Gravity Based StructuresThe Gravity Based Structure (GBS) component includes costs for the concrete gravi

6、ty base together with all reinforcement, the transition piece, mechanical outfitting, grouting and ballasting systems and oil storage facilities. Gravity based structures GBS: concrete GBS either conventional or monotower can be selected with or without storage. Typically used in the Norwegian secto

7、r of the North Sea.The offshore pipelines component allows calculation of pipeline sizes, wall thicknesses, materials, fittings, installation, design and project management costs for pipelines and riser systems. The pipelines can include single phase or multiphase product export, water injection, ga

8、s injection and gas lift lines to shore, to new or existing platforms (fixed or floating) and to existing pipelines for tie-in. The materials costs include for linepipe, flexible risers and support systems, steel risers (new or retrofit), shore approaches, corrosion protection, weight coating, catho

9、dic protection, insulation, fixtures and fittings. Installation can be by a range of vessels suitable for the combination of pipeline diameter and water depth. Installation vessels include the lay barge, reel ship or heavy lift vessel as well as DSVs for tie-ins and testing, trenching and survey ves

10、sels. Pipelines: are defined by size, wall thickness, material and installation. The cost includes for risers, pipeline tie-ins and shore approaches. Used in water depths down to 4,000m.The semi-submersible component includes costs for the vessel purchase, mooring system, accommodation units, upgrad

11、ing of converted vessels, installation and project management. Semi-submersible: second to fifth generation new builds and second to fourth generation converted semi-submersibles can be selected with or without rigs. Used in water depths down to 4,000m.The spar buoy component includes costs for the

12、hull, mooring system, risers materials and fabrication plus installation, design and project management.The tanker component includes costs for the vessel purchase, mooring system, quarters (for marine crew), vessel upgrades, installation and project management.Tension Leg Platformsa conventional TL

13、P and a mini TLP.The conventional TLP hull is assumed to have four columns arranged in a square with a ring pontoon at the base of the columns. The topsides, including the deck, sits on the columns and a group of tethers attached to each column terminates at the seabed in a piled foundation. Tension

14、ed steel risers are assumedCatenary Anchor Leg Mooring (CALM) buoys, SingleArticulated Leg Moorings (SALMs) Floating Loading Platforms (FLP). CALM: A catenary anchor leg mooring consisting of a buoy supporting fluid swivels anchored using a spread pattern of four or six chains. Connection to the tan

15、ker is via floating hose if only shuttle tankers are used and via rigid yoke if a permanent storage tanker is used.SALM: A single articulated leg mooring based on the EMH articulated column design. The mooring system consists of a piled or gravity base, a solid or lattice construction articulated to

16、wer, rigid riser, rotating head and extended boom to support the loading hose. Temporary quarters and helideck are included.FLP: A floating loading platform. This is similar in principle to the CALM buoy but is on a larger scale and includes temporary quarters and helideck.FLPs are not recommended i

17、n water depths less than 50m. In shallow water, (25m), it is not possible to install a SALM or FLP and therefore CALM is the only recommended option. SALMs are not recommended for water deeper than 250m.The drilling component estimates the drilling costs including rig hire (for jack-up and semi-subm

18、ersible rigs), drill crew, well equipment, consumables, materials, conductors, etc. For a tender assisted platform rig the rig hire includes only for the hire of the tender assist vessel and its marine crew.Several drilling operations can be specified on a development and the total drilling operatio

19、ns can be a combination of platform wells, subsea wells and exploration/appraisal wells. However, if a combination of rig types is required, then each should be costed as a separate drilling component.Equipment CostsThe configuration of the Xmas trees is typically subsurface safety valve, lower mast

20、er valve, upper master valve, choke valve, wing valve and (if subsea) tree cap.The wellhead sits below the Xmas tree and typically includes a casing hanger, casing head spool, tubing hanger, tubing spool and seals.Completion equipment costs vary dependent on the type of completion selected.ESP costs

21、 include for the downhole equipment plus the topsides electrical equipment. The downhole equipment typically includes the pump, motor and seal assembly, a packer, motor lead extension cable and a nominal 2000m of power cable per pump. The topsides electrical equipment includes for a step-up transfor

22、mer, junction box and variable speed controller. If the wells are subsea, the subsea component will include electrical cables in the umbilicals to power the ESPs. Subsea: template or cluster wells linked to manifolds, covers flowlines, umbilicals and risers. Includes features such as diver or diverl

23、ess installation, steel or flexible flowlines, round trip pigging, trawl protection structures and new or retrofit risers. Used in water depths down to 4,000m.SubseaThe subsea component provides costs for all subsea equipment and materials including:qClusters, templates and satellites.Commingling an

24、d riser base manifolds.qProduction, test, injection and gas lift flowlines.qRisers and riser systems.qUmbilicals.qPlatform controls.Development typeThe default development type is Cluster manifold but Template manifolds and individual Satellite wells are also available. The selected development type

25、 is used to generate the default subsea configuration. Selecting Cluster or Template does not mean that satellite wells will not be included as the default configuration is derived based on matching the exact well count. A combination of clusters, templates and satellites can be specified in the sub

26、sea schematic. Any changes made in the subsea schematic will not update the development type.Features 1Through piggingIncludes a minimum of two production flowlines of equal size to allow round trip pigging from the host facility when a new subsea configuration is generated. If a test/service line i

27、s present this forms one of the flowlines.Chemical injectionIncludes chemical injection flowlines to all templates, clusters or satellite production wells when a new subsea configuration is generated. Chemical injection lines can be included in the umbilical so this should only be selected if a larg

28、er diameter chemical injection flowline (in addition to the chemical tubes in the umbilicals - typically 1” diameter) is required for batch dosing the wells.Test serviceIncludes a test/service line in every flowline group when a new subsea configuration is generated.Gas liftAllows for all production

29、 wells to be gas lifted and includes a gas lift flowline in every flowline group when a new subsea configuration is generated. Gas lift rateThe required ratio of gas lift to produced oil, used to size lift and production lines. This only becomes active if Gas lift is selected and defaults to 600 scf

30、/bblRiser systemsWhen flexible risers are included, the cost for a riser support system consisting of an arch and buoy is included. Each system can support up to five risers. The number of riser systems required is determined assuming the maximum total diameter of risers that can be handled by any o

31、ne system is 40 inchIt should be noted that barges are probably most suitable to shallow water/swamp regions. As such they are most applicable in the Far East/African regions. Some geographical databases have no suitable areas for barge installation and are not provided with barge cost data, e.g. No

32、rth Sea regions. If it is required that a barge is to be used in such a region, the cost data should be manually entered.decommissioning cost estimate to each topsides, jacket and pipeline. Decommissioning, dismantling, removal and disposal costs are considered along with associated costs for design

33、, project management, insurance and certification.Oil Processing ToolbarToolbar buttonButton functionInsert separator / insert test separator (2nd occurrence of symbol to the right of the stabiliser icon)Insert heat exchanger Insert dehydratorInsert desalterInsert reboiled stabiliserDelete componentPrint. Print out contains the oil processing schematic plus a table containing the flow, temperature, pressure, oil SG and gas molecular weightPrint preview