Subsea processing. IFEA seminar: Subsea Kraftforsyning Stavanger, 25 mai Classification: Internal

Transcription

1 Subsea processing IFEA seminar: Subsea Kraftforsyning Stavanger, 25 mai Classification: Internal

2 Subsea Processing Introduction to Subsea Processing Why, where, what is subsea processing Key drivers Key technologies How they work Relevant experience in Statoil Subsea processing future needs and requirement for subsea HV power 2 - Classification: Internal

3 Subsea in Statoil Lufeng Today more than 50% of Statoil production is from subsea production systems Åsgard Statoil has approximately 480 subsea wells Tordis Tyrihans Ormen Lange Number of wells increasing with new tie-in projects to existing facilities Gullfaks Troll Pilot Subsea processing used to increase recovery 3 - Classification: Internal

4 What is subsea processing? Manipulating the well stream between wellhead and host. Technology Infrastructure Pipelines By: Hydrocarbon boosting Separation systems Gas compression (Raw seawater injection) Asset Prerequisites and enablers: Long distance / high voltage power Advanced process monitoring and control Cost-efficient installation, maintenance and retrieval 4 - Classification: Internal

5 Why subsea processing in Statoil? 480 subsea wells more than 50% of Statoil s total production. Benefits: Increased hydrocarbon recovery Accelerated production Reduced CAPEX / OPEX HSE These benefits typically become more significant in fields with: Deeper water Longer step-out / distance Lack of infrastructure Harsher environments Enabling technology (e.g. ultra-deepwater, tight, deep reservoirs and difficult fluids) 5 - Classification: Internal

6 Effects of subsea boosting P Pump or compressor 6 - Classification: Internal

7 Production Effect of subsea boosting: Boosted Production Profile Normal Production Profile time Accelerated Production Increased Total Recovery Shorter Recovery Time Time 7 - Classification: Internal

8 Subsea Processing Principle (Boosting) Pfwh Inflow Performance Relation (IPR) Natural Flow MPP Discharge pressure Curve Boosted Flow dprequired System Resistance Curve dq (Flow Increase) MPP must be able to Pump Q2 with dp Q1 Q2 Q 8 - Classification: Internal

9 Effects of subsea separation P 9 - Classification: Internal

10 Subsea Processing Principle (Separation & Boosting) Pfwh Inflow Performance Relation (IPR) With water Natural Flow With water Natural Flow Without water System Resistance Curve with water Removal of water (separation) dp Requirement Boosting With water Without water System Resistance Curve without water dqinflow - Boosting Less dp required with separation, for a given inflow & pipeline ID Qinflow 10 - Classification: Internal

11 Relevant experience in Statoil 11 - Classification: Internal

12 Statoil subsea processing history stepwise development Tordis Start Poseidon multiphase pump development 1996 Gullfaks First multiphase Pumps (topsides, part of Framo commercialisation) Pipe separator 1997 Lufeng Subsea pumps 2000 Troll Subsea water removal and injection 2003 Norne Technology program Subsea separation concept developments 2007 Tordis Subsea water removal & 2005 injection, oil & Troll Pipe gas boosting separator Qualifications Subsea water removal Troll Pilot 10 years Tyrihans Subsea raw seawater injection (ready for operation) Tyrihans SRSWI Lufeng Operation Classification: Internal

13 Statoil experience with subsea pumps 1986 Poseidon IFP,Total, Statoil 1994 Gullfaks A topside 1997 Lufeng 1999 Troll Pilot 2007 Tordis 2009 Tyrihans 0,4 MW 0,4 MW 1,6 MW 2,3 MW 2,7 MW 13 - Classification: Internal

14 Subsea pumps applications today: Well stream boosting Multiphase boosting Helico axial Twin screw Centrifugal/Hybrid/ESP (limited GVF) Subsea separation and boosting Centrifugal Hybrid combination of MP and centrifugal ESP Water injection Centrifugal 14 - Classification: Internal

15 Lufeng field development Subsea pumps: - Enabeled field development - Extended field life from 5 to 12 years Distance to host: Water Depth: Pumps: Flow: Drive system: Subsea power: 1 km 330 m 5x0.4MW (SPP) m3/d 5x VSD Prod. start-up : 1997 Prod. Shut-down: 2009 Direct drive 15 - Classification: Internal

16 Statoils experience with subsea separation Tordis Troll Pilot Norne Technology Program Troll pipe separator qualifications 2011 Pazflor Total operator 16 - Classification: Internal

17 Troll Pilot field development Installed 1999 Started 2000 Still stable and profitable operation after 10 years on the seabed Currently injecting bbl/d -> increasing oil capacity at Troll C Distance to host: 2 km Water Depth: 350 m Pump: 1.8MW (SPP) Flow: 63,000BBLD (25,000BBLD oil) Drive system: VSD Subsea power: Direct drive Prod. start-up : Classification: Internal

18 Troll Pilot Operational experience 2000: Electrical earth fault in wet mate connector during first start-up Fixed in : Pump required intervention 2003: Inductive level instrument lost function, due to an electrical jumper 2005/06 The inductive level detector jumper replaced 2007: Pump upgrade From % availability 18 - Classification: Internal

19 Tordis SSBI field development Existing Tordis subsea PLIM Distance to host: 12 km Water Depth: 210 m Pumps: 2x2.3MW (SPP+MPP) Flow: 189,000BBLD (57,000BBLD oi Drive system: 2x VSD Subsea power: Direct drive Prod. start-up : 2007 WI Well SSBI station Ambition: Increase oil recovery from 49% to 55% (~36.5 Million bbl) 19 - Classification: Internal

20 Tordis Operational Experience 100% availability of subsea processing station Sand handling system working properly Oil content way below specified 1000 ppm Tordis without SSBI: Oil: bpd Total Liquid: bpd Water cut: 80 % Tordis including SSBI: Oil: bpd Total liquid bpd Water cut: 80 % Water inj: bpd 20 - Classification: Internal

21 Statoils experience with subsea water injection 2009 Tyrihans RSWI installed 2010 SWIT Phase 1 (Statoil not part of JIP) 2011 SWIT Phase Classification: Internal

22 22 Tyrihans SRSWI field development Experience transfere: Integrated control system Pumps 100 % available since installation Awaiting injection well Distance to host: 40 km Water Depth: 270 m Pumps: 2x2.5MW SPP Flow: 88,000BBLD Drive system: 2 x topside VSD s Subsea power: 2 x subsea transformers Prod. start-up : 2011 W (SRSWI) 22 - Classification: Internal

23 Subsea Compression 2014? - Topside experience, KBS etc - Compact compressor - Compact gas scrubbers - Power system - All electric control systems - Material testing Gullfaks SCS Åsgard Subsea Compression Ormen Lange SCS Pilot Snøhvit future development 23 - Classification: Internal

24 Ongoing subsea compression projects Field Gullfaks Åsgard Ormen Lange * Planned Installed 2014 / Design life (yrs) Depth (m) Tieback (km) No of units Pressure boost (bar) Power (MW) VSD Topside Topside Subsea * Operated by Shell 24 - Classification: Internal

25 Subsea Compression. Not only a submerged compressor Subsea process equipment Subsea power equipment Picture from Ormen Lange Pilot 25 - Classification: Internal

26 26 - Classification: Internal

27 Future needs Future needs Longer step outs Subsea power distribution and subsea VSDs, Larger dp pumps Deeper waters Colder 27 - Classification: Internal Larger hydrostatic pressures Deeper reservoirs Environments Heavier fluids 500 km step-outs 3000 m water depth 100 MW power

28 Longer step outs New areas - e.g. Barents sea limited infrastructure larger step out distances from host Today: Tyrihans ca 43 km > 200 km Limited volumes in place long tie backs if separation to transport quality cost allows Impact for Subsea power: High dp pumps to overcome long distance transportation Larger motors to reduce number of pump units Subsea coalesher Local subsea water injection Subsea power distribution Larger motors, subsea VSD and HV power distribution, Local power?, 28 - Classification: Internal

29 Deeper: GoM drivers Statoil leases in deep water ( m) Large volumes in place; low initial recovery factor Paleogene reservoirs: Relatively low GOR Relatively low bubble point Low permeability low(er) operating pressure Deep reservoirs; 7000 m below seabed High shut-in pressure; casing, penetrators Needs: Increased reliability/regularity Reduced intervention costs Subsea HIPPS ESP MPP SPP Seabed pumps from first oil P (Single phase followed by High dp MPP/hybrid pumps) Subsea ESPs and subsea HV power distribution 29 - Classification: Internal

30 Colder Arctic areas Long distance power supply Subsea HV power distribution Lager pumps/motors to reduce number of units Separation to transport quality Heavier fluids Lager motors In-field flowline heating Subsea HV power distribution Subsea coalesher SLPS 30 - Classification: Internal

31 Ambitions for subsea processing and subsequent subsea HV power Ambitions Efficient transport of conditioned well streams over long distances in long term up to 500 km utilizing separation, liquid boosting and wet gas compression. Develop abilities to access resources in deep water and harsh environments. Also heavy oil prospects Ensure that subsea gas compression is an integral part of future developments in accessing the international gas value chain Maintain production rates in the Norwegian Continental Shelf through deployment of subsea processing as a major part of Statoil s increased hydrocarbon recovery initiative. Needs for subsea HV power Efficient subsea power transmission systems Reliable/ high endurance rotating machinery and subsea HV power equipment Advanced processing systems will require additional utility systems -> power and power distribution Cost effective solutions (not only key equipment, but pipes, power lines, umbilicals and distribution systems etc) Subsea HV power distribution and control Lager units; e.g up to 5-6 MW pumps, 15 MW compressors Smaller units within existing technology Smaller compressor units; 3-6 MW Subsea distribution and power control (host platform is weight and space limited) We seek your ideas to meet our ambitions 31 - Classification: Internal

32 Thank you Subsea processing at IFEA Subsea power conference 2011 Birgitte Nordheim Tveter Principle Engineer, subsea processing Classification: Internal