Natural gas Dry gas / sales gas - NTNU

TPG4140 – NATURGASS 

NTNU 

Gasstransport 

22. oktober 2003 

Morten Aamodt 

Fagleder system design 

STATOIL ASA 

morm@statoil.com 

1

Gasstransport 

� Innhold 

� Del 1: 

� Innledning 

� Gasstransport norsk sokkel 

� Maksimal utnyttelse av gass infrastrukturen 

� Del 2: 

� System design av rørledninger 

� Utbygging av nye gassfelt 

� Kristin 

� Ormen Lange 

� Snøhvit 

TPG4140 – NATURGASS 

NTNU 

2

Remaining Undeveloped Discovered Remaining Undeveloped Discovered gas: gas: gas: 6954 8763 6954 8763 1713 TCF 

TCF 

TCF 

3

Norwegian Pipeline System 

� Technical services are provided by Statoil 

for the world's most extensive submarine 

gas pipeline system, which runs from 

Norway and its offshore fields to continental 

Europe. 

� 6000 km pipelines (30” – 42”) 

� Transport capacity approx. 270 MSm3/d 

� Statoil is a leader in the construction of 

large-diameter pipelines in deep water. The 

group has developed extensive expertise in 

pipeline technology and the operation of 

advanced pipeline systems. 

� On 1 st January 2002, Gassco became the 

operator for most of the gas pipeline 

systems from the Norwegian continental 

shelf. 

� On 1 st January 2003, GasLed became the 

owner for most of the gas pipeline systems 

(Statoil share 20.38%). 

4

Norwegian Pipeline System 

Gas pipeline 

system 

Size each 

leg, inch 

Length 

km 

Depth 

m 

Statpipe 

Oper. 

Year 

1985 28, 30, 36, 36 880 300 

Zeepipe 1993 30, 40 850 80 

Europipe 1995 40 670 70 

Troll gas 1996 36, 36 130 360 

Zeepipe II 1996 40, 40 610 370 

Haltenpipe 1996 16 250 360 

Franpipe 1998 42 840 70 

Europipe II 1999 42 660 300 

Åsgard Transp 2000 42 700 370 

Heidrun/Norne 2001 16 200 350 

5

Natural gas 

Natural 

gas 

� Dry gas / sales gas: Consists mainly of methane, ethane and some LPG. The gas will not 

condense at normal conditions. 

� Rich gas / wet gas: Consists mainly of methane, ethane, LPG, but has some naphtha 

and condensate. The gas will condense at normal conditions. 

� LNG (Liquefied Natural gas): Dry gas cooled to form liquid phase (-163°C). 

� LPG: Liquefied Petroleum Gas 

� NGL: Natural Gas Liquids 

Methane CH 4 

Ethane C 2 H 6 

Propane C 3 H 8 

Iso-Butane i-C 4 H 10 

Normal Butane n-C 4 H 10 

Naphtha 

Condensate (C5+) 

LPG 

NGL 

6

Conventional transport to shore 

� Oil is transported to shore through pipeline or tanker (e.g. Mongstad) 

� Rich gas is transported in pipeline to gas processing plant for separation 

of liquid products and gas conditioning to form dry export gas 

� Dry gas (sales gas) is exported in pipelines to continental Europe / UK 

Kårstø gas terminal 

• Receives rich gas from Statfjord and 

Åsgard fields 

• Receives Sleipner condensate 

• Exports dry gas through Statpipe 

and Europipe II 

• Exports liquid products: 

ethane, propane, butane, naphtha 

and condensate 

7

Europe’s largest gas treatment plants 

� Kollsnes and Kårstø can 

handle 15 per cent of all 

European gas requirements 

� They serve as hubs for gas 

exports by pipeline and 

tanker 

� Kårstø receives 600 tanker 

calls annually 

The Kårstø gas processing complex. 

8

Progress in transport technology 

� Wet gas (multiphase flow) transport from field to 

shore (Troll, Kvitebjørn, Snøhvit, Ormen Lange....) 

� Long distance multiphase transport of gas, 

condensate, water and glycol in the same pipeline 

� Removing the process to shore (Snøhvit, OL) 

� Flow assurance (hydrate, liquid accumulation,….) 

� Control and operation challenges 

� Measurement challenges 

9

Wet gas transport 

Troll gas 

� Troll contains 60 % of overall gas 

reserves of Norway 

� Troll gas comprises Troll A wellhead 

platform, two 67 km long wet gas 

pipelines to Kollsnes gas process plant 

� Liquid is separated from the gas at 

Kollsnes (DPC process) 

� Condensate is exported to Mongstad 

� Dry gas is exported to continental Europe / 

UK through the gas transport pipelines Zeepipe 2A & 2B 

� Kvitebjørn - Kollsnes wet gas pipeline will come into production Oct 04. The 

Kvitebjørn gas will be converted to natural gas liquids (NGL) at the extended 

Kollsnes plant. 

10

Kollsnes 

11

Kollsnes som blandebatteri 

Felt CO2 

Troll A 0.30 

Troll B&C 1.00 

Kvitebjørn 3.80 

Visund 1.25 

From DPC 0 

0.77 % CO2 

Pipeline 

Compressor “A” 

0 MSm³/sd 

Kollsnes - Sleipner 

21 MSm³/sd 

157.12 bara pipeline inlet pressure 

Train No. 1 

1.13 % CO2 

0.0 MSm³/sd 

Pipeline 

0.8 % CO2 0.77 % CO2 Compressor “B” 

0 MSm³/sd Comp 

A 

ZpIIA ZpIIB 

1 0 

Pipeline 

B 

C 

0 

1 

1 

0 

0 0.77 % CO2 Compressor “C” 

0 MSm³/sd D 0 1 

From DPC 

E 1 0 

Train No. 2 

0.0 MSm³/sd 

0.8 % CO2 1.13 % CO2 

Pipeline 

Compressor “D” 

21 MSm³/sd 

F 0 

1: Deliver 

0: Closed 

1 

From DPC 

Train No. 3 

1 1.13 % CO2 

Pipeline 

Compressor “E” 

21 MSm³/sd 

0 MSm³/sd 

2.45 % CO2 

Each compressor deliver to 

only one pipeline 

37.0 MSm³/sd 173.01 bara pipeline inlet pressure 

0.8 % CO2 Future Pipeline 

41 MSm³/sd 

1 

3.84 % CO2 Compressor “F” 

20 MSm³/sd 

Kollsnes - Draupner 

From new NGL 

extraction train 

Total 62 MSm³/sd 

25.0 MSm³/sd 78 bara 

3.84 % CO2 1: Running 

0: Down 

12

Sleipner – knutepunkt for norsk gass 

13

Terminalen i Dunkerque 

14

GasLed area A, B, C and D 

St Fergus 

Dunkerque 

Sleipner 

Tune 

Huldra 

Oseberg 

Ekofisk 

Grane 

Kv.b. 

Heimdal 

Zeebrügge Norsea EMS 

Dornum 

Kårstø 

EXT: Extraction 

ERSL: Ethane refinement, incl. storage and loading 

CSL: Stabilisation condensate, incl. storage and loading 

FE: Fractionation ethane 

FSL: Fractionation propane/butanes/naphtha incl. storage and loading 

Troll 

Kollsnes Sture 

Snurrev. 

Draupner/ 

Jotun/ 

Balder 

Vestp. 

EXT 

Gullfaks 

Statfjord 

A 

Veslefrikk 

Brage 

ERSL 

CSL 

FE 

FSL 

C 

D 

Mikkel 

ÅSG 

Draugen 

Norne 

Heidrun 

B 

Outside system boundary 

Radial entry point 

Radial exit point, pay a to b tariff 

Rich/dry Rich/dry point, point, pay pay extraction extraction tariff 

tariff 

Process Process exit exit point, point, pay pay fractionation fractionation tariff 

tariff 

Dry Dry gas gas entry entry point, point, pay pay entry entry tariff 

tariff 

Gas exit point, pay exit tariff 

"Area" 

Tjellb. 

15

Transport capacity in gas pipelines 

Terms and conditions 

� Hydraulic Capacity (Hyd) 

The maximum volume of natural gas physically possible to transport through the pipeline 

under given conditions 

� Available Technical Capacity (ATC) 

The capacity may be limited by a system boundary condition, e.g. lack of export 

compression to fill the pipeline. The ATC is the actual capacity available for a given period 

� Committable Capacity (Com) 

The committable capacity takes into account both the fuel consumption and an operational 

flexibility factor. The relation between the ATC and the Com is given by: 

� Bookable capacity 

This capacity defines the maximum allowed booking level. The capacity equals the Com 

minus the retained capacity as defined in the Booking Manual 

� Booked Capacity 

The sum of the converted bookings as of 31.12.02 and later bookings as recorded on 

Gasviagasled.com 

Q 

COM 

= 

( 1 

Q 

ATC 

Opflex 

+ Fuel ) * ( 1+ 

) 

100 100 

16

GasLed System Capacity Report 

Area D 

Exit Point 

Zeepipe 

Franpipe 

Statpipe/ Norpipe 

Europipe 

Europipe 2 

Vesterled 

Period/ Contract 

Year 

Hydraulic 

Capacity 

Available 

Technical 

Capacity 

Committable 

Capacity 

[MSm³/d] [MSm³/d] [MSm³/d] 

2003 41.9 41.9 40.9 

Jan.-March 2004 

CY2003 

41.9 42.7 41.7 

2004 41.9 41.9 40.9 

2005-2028 41.9 41.9 40.9 

2003 53.8 50 50 

2004 53.8 50 50 

2005-2028 53.8 50 50 

2003 44.9 31.3 30 

2004 44.9 31.3 30 

2005-2028 44.9 31.3 30 

2003 55.2 45.8 44.5 

2004 55.2 45.8 44.5 

2005-2028 55.2 45.8 44.5 

2003 72.6 55.6 54 

2004 72.6 56.7 55 

2005-2028 72.6 63.2 62.3 

2003 39.2 29.2 28.4 

2004 

January - July 

39.2 38.7 

37.6 

2004 

August - 

December 

39.2 39.2 38.1 

2005-2028 39.2 38.7 37.6 

17

Reservoar 

betingelser 

Økt utnyttelse av gassrørledningene – 

en oversikt ! 

Rørledningsdesign 

Nye design normer 

Trykksprang 

Optimalisering av system og drift 

Redusert operasjonell fleksibilitet 

Kapasitetstester 

Reduserte operasjonelle marginer 

Teknologi utvikling: Flytforbedrer 

Forsterkningsløsninger 

Markedsbetingelser 

Økt utnyttelsesgrad av stålet i rørveggene 

Bruke høyere andel av hydraulisk kapasitet 

Reell kapasitet/reduserer usikkerhet 

Marginer nødvendig for å oppnå høy 

regularitet 

Utvikling av flytforbedrer for rikgass 

ledninger pågår 

Midtveis kompresjon og parallelle rør 

18

Kapasitetstest gir kunnskap om reell 

kapasitet 

Forutsetninger for en vellykket test: 

�Test avhengig av stabile forhold (volum trykk, temperatur) 

�Test bør gjøres med så høy rate som mulig 

�Nøyaktig instrumentering (kalibrering) 

Kapasitet MSm³/d 

p ut1 

∆p 

q 1 

p inn1 

p test 

q 2 

p inn2 

Etter kapasitetstest 

Design 

p 

Tunings parametere: 

�friksjonsfaktor (ruhet) 

�varmeovergang 

19

Increased pipeline capacity 

Zeepipe IIA 

Zeepipe IIB 

Europipe II 

Europipe 

Franpipe 

Zeepipe I 

Statpipe 

Statpipe RG 

ÅT 

0 10 20 30 40 50 60 70 80 90 

Design Today Upgraded potential 

20

Utnyttelse av stålet i rørledninger på land 

og i sjøen 

� Rørledninger skal tradisjonelt ha samme designtrykk langs hele lengden 

� Designsituasjonen for gassrør er en pakket ledning mot stengt nedstrømsventil 

� Lange landrørledninger har relativt lavt designtrykk og mange 

kompressorstasjoner 

� Kompresjon på land er relativt billig, begrenset trykkfall mellom stasjoner 

� God gjennomsnittlig utnyttelse av stålet i røret som trykkbeholder 

� Lange sjørørledninger har høyt designtrykk, men ikke kompresjon 

underveis 

� Utvendig overtrykk krever økt veggtykkelse som kan utnyttes for innvendig trykk 

� Kompresjon gjøres oppstrøms, stort trykkfall til nedstrøms ende 

� Ikke så god gjennomsnittlig utnyttelse av stålet i røret som trykkbeholder 

p d 

Landrør 

Trykkfallskurve 

Lavere utnyttet rørmateriale 

p d 

Sjørør 

Trykkfallskurve 

Lavere utnyttet rørmateriale 

Oppstrøms ende Nedstrøms ende Oppstrøms ende Nedstrøms ende 

21

Dimensjoneringskriterier 

� Forenklet kan man si at veggtykkelsen til en undervanns rørledning dimensjoneres 

for: 

� maksimum innvendig driftstrykk (driftsfasen) 

� ytre vanntrykk (installasjonsfasen, tomt rør) 

� I seksjoner der det ytre vanntrykket er dimensjonerende, vil veggtykkelsen i røret 

være større enn det som er nødvendig for røret som en trykkbærende beholder, 

noe som bør utnyttes til å øke innvendig trykk i røret dersom dette er praktisk 

mulig. 

Nødvendig veggtykkelse 

(mm) 

35 

30 

25 

20 

15 

10 

5 

0 

0 200 400 600 800 

Vanndybde (m) 

Potensial for økt indre trykk 

Veggtykkelse for 

gitt innvendig 

designtrykk 

Kollaps 

p.g.a.utvendig 

overtrykk 

22

Høyere utnyttelse av røret som 

trykkbeholder 

� Kan stålet i rørveggen utnyttes bedre? 

� Avanserte verktøy for tilstandsovervåkning under 

drift 

� God skadestatistikk, overtrykk er ikke skadeårsak 

� Bedre stål egenskaper og toleransekontroll ved 

fremstilling av rørene 

� Bedre sveise og testprosedyrer 

� Er det nødvendig at en lang gassrørledning skal tåle 

samme trykk nedstrøms som oppstrøms? 

� Under vanlig drift er trykkfallet betydelig over 

lengden av rørledningene 

� Nedstrøms enden ser sjelden eller aldri maksimalt 

driftstrykk 

� Men designstandarder og industripraksis forutsetter 

overtrykksbeskyttelse på det stedet der 

designtrykket endres 

Utvendig diameter De 

Innvendig diameter Di 

Di < De 

23

Trykksprangkonsept - prinsipp 

� To eller flere nivåer for designtrykk langs rørledningen 

� Ingen lokal overtrykksbeskyttelse der designtrykket reduseres 

� Trykk-kontroll og overtrykksbeskyttelse baseres på overføring av driftsdata fra nedstrøms 

enden til oppstrøms enden ved hjelp av høypålitelig kommunikasjon 

� Sentrale forutsetninger 

pd 

� Trykkfallskurven skal under normal drift alltid ligge under designtrykk-kurven 

� Utjevningstrykket skal under normal drift ikke kunne overstige laveste designtrykk 

� Utjevningstrykket skal under unormale driftssituasjoner ikke kunne overstige laveste 

maksimum tillatt tilfeldig trykk "maximum incidental pressure” (MIP) 

Konstant designtrykk 

pd1 

To designtrykknivåer 

Utjevningstrykk 

Trykkfallskurve Trykkfallskurve 

Lavere utnyttet rørmateriale Lavere utnyttet rørmateriale 

Oppstrøms ende Nedstrøms ende Oppstrøms ende Nedstrøms ende 

pd2 

24

Trykksprangkonseptet - anvendelser 

� Zeepipe IIA (implementert) 

� Oppstrøms design trykk økt fra 172 til 191 barg 

p.g.a. høyt utvendig trykk på dypt vann 

� Kapasiteten økt med 40% 

� Europipe II (implementert) 

� Landfall forberedt med design trykk 163.4 barg (tunnel 

Europipe I) 

� Oppstrøms design trykk designet for 191 barg 

� Kapasitet økt med 22% 

� Forlengelse av Åsgard Transport til Norne/Heidrun 

(ikke implementert) 

� Åsgard Transport har design trykk 212 barg 

� Norne-Heidrun rørledningen har design trykk 280 barg 

� Kapasiteten i Åsgard Transport kan opprettholdes 

� Oppgradering av Zeepipe IIA/B (godkjent av 

myndigheter) 

� Basert på DNV OS-F101 

� Oppstrøms design trykk økes til 

� Zeepipe IIA; 200.3 barg 

� Zeepipe IIB: 205.2 barg 

� Tre design trykk nivåer for begge rørledningene 

� 24% økt totalkapasitet ut fra Kollsnes 

191 barg 

163 barg 

280 barg 

212 barg 

191 barg 

172 barg 

Norne 

Zeepipe IIA 

Kollsnes KP 135 Sleipner 

Europipe 2 

Kårstø KP 350 Dornum 

Åsgard transport 

Åsgard Kallstø 

25

Zeepipe IIA 

Oppgradering basert på DNV OS-F101 

Intervensjonsarbeid 

ASME B31.3/8 

Avvik fra DNV OS-F101 

Eksisterende trykksprang 

KP 134.8 

Design kode 

DNV OS-F101 TBK 

Test trykk 

Design trykk 

238.2 barg 

200.3 barg 

219.1 barg 

179.6 barg 172 barg 

26

Technology drivers 

Natural gas 

Snøhvit + 

Western 

Africa 

NCS gas 

Snøhvit 

LNG 

Expand NCS business: 

Expand NCS business: 

• Increase capacity of current pipelines 

• Increase capacity of current pipelines 

• Tie-in of new infrastructure 

• Tie-in of new infrastructure 

• Extraction of NGL (Kårstø) 

• Extraction of NGL (Kårstø) 

• CO2 and N2 emissions from processing 

• CO2 and N2 emissions from processing 

• LNG production (Snøhvit) 

• LNG production (Snøhvit) 

• Mega-scale methanol production 

• Mega-scale methanol production 

• Power or combined heat and power production from 

• Power or combined heat and power production from 

gas (Kårstø, Kollsnes, Skogn, others) 

gas (Kårstø, Kollsnes, Skogn, others) 

The 

Caspian 

New 

New 

business 

business 

opportunities: 

opportunities: 

• 

• 

Mega-scale 

Mega-scale 

GTL 

GTL 

plants 

plants 

(Iran) 

(Iran) 

• 

• 

Floating 

Floating 

LNG 

LNG 

production 

production 

(Nnwa) 

(Nnwa) 

• 

• 

Deep 

Deep 

water 

water 

pipelines? 

pipelines? 

• 

• 

Onshore 

Onshore 

pipelines? 

pipelines? 

27

Gasstransport 

Del 2 

� System design av rørledninger 

� Utbygging av nye gassfelt 

� Kristin 

� Snøhvit 


28

Pipeline System Design 

Work process 

Thermohydraulic 

analysis 

Internal diameter, 

capacity, pressure 

and temperature 

profile, etc. 

Functional 

requirements; 

gas routing, 

regularity, 

gas quality, 

agreements 

Functional 

requirements, 

Regularity, 

Deliverability 

Overall 

Operational 

Philosophy; 

Control and Safety 

System, 

Environment, etc. 

Control and Safety 

Philosophy 

Boundary conditions and technical interface between platform – pipeline – terminal 

QA 

System design 

concept 

Pipeline System 

Diagram, Process 

Flow Diagram 

P&ID’s 

29


System definition 

� The extent of the pipeline system, its functional requirements and applicable 

legislation should be defined and documented. 

� The extent of the system should be defined by describing the system, 

including the facilities with their general locations and demarcations and 

interfaces with other facilities. 

� The functional requirements should define the required design life and design 

conditions. Foreseeable normal, extreme and shut-in operating conditions with 

their possible ranges in flowrates, pressures, temperatures, fluid compositions 

and fluid qualities should be identified and considered when defining the 

design conditions. 

� Terms and definitions 

Petroleum and natural gas industries 

Pipeline transportation systems, ISO 13623 

OS F-101: Submarine Pipeline Systems 

30


Terms and definitions 

� Pipeline system 

� A pipeline with compressors or pump stations 

� Pressure reduction stations 

� Metering 

� Tankage 

� Supervisory control and data acquisition system (SCADA) 

� Safety systems 

� Corrosion protection systems 

� And other equipment, facility or building used in the transportation of fluids 

� Pipeline 

� Those facilities through which fluids are conveyed, including pipe, pig traps, 

components and appurtenances, up to and including the isolation valve. 

Petroleum and natural gas industries 

Pipeline transportation systems, ISO 13623 

31


Design premises 

� Pipeline Route 

� Length 

� Bathymetric profile 

� Environmental Conditions 

� Air temperature 

� Sea bottom temperature 

� Ground temperature 

� Geo-technical data (soil conditions) 

� Pipeline Data 

� Design pressure 

� Design temperature 

� Internal diameter 

� Wall thickness 

� Internal coating 

� Concrete coating 

� Insulation 

� Trenching/dredging 

� Gravel/rock dumping 

� Gas composition 

� Gas properties 

� Equation of state 

� Friction equation 

� Internal roughness 

� Transport specification 

� Sales gas specifications 

� Pressure Control System 

� Pressure regulating 

� Pressure safety 

� Pig trap arrangement 

� Pigging philosophy 

� Pipeline valve philosophy 

� Future requirements 

32


Gas value chain 

� The objective of the system design is to develop overall transport solutions for 

the gas chain from the field to the market which will maximize the value of the 

liquid- and gas products and without any unreasonable external conditions for 

any third party (fields or transport systems). 

� The main objective in design and operation of gas pipeline systems is to 

deliver gas quantities nominated by the buyers within the desired quality 

specifications. Within reasonable technical and economical limits and relevant 

agreements, necessary means to ensure high availability and regularity will be 

used. 

33


Hydraulic analysis 

� The hydraulic design of a pipeline system is part of the conceptual 

development of a gas pipeline project. 

� The hydraulics of the pipeline system should be analysed to demonstrate that 

the system can safely transport the fluids for the design conditions specified 

by the system definition, and to identify and determine the constraints and 

requirements for its operation. This analysis should cover steady-state and 

transient operating conditions. 

� The hydraulic design is an optimisation process of several system parameters: 

� Boundary conditions both at upstream and downstream end 

� pressure and temperature 

� Physical transport properties; gas composition 

� Design gas flowrate 

� Internal wall roughness 

� Environmental conditions; ambient temperature, overall heat transfer coefficient 

34


Hydraulic analysis 

� Predict the pipeline capacity and minimize the uncertainty 

� Describe the function loads for the pipeline design 

� Pressure profile 

� Temperature profile 

� Density profile (fluid) 

� Velocity profile 

� Design cases: 

� Normal operation, start-up, planned shut-down, etc. 

� Not planned operation, emergency shut-down, depressurisation, etc. 

� Emergency preparedness analysis; accidents, pipe rupture, leakage etc. 

35

Pressure, barg 

240 

220 

200 

180 

160 

140 

120 

100 

Ormen Lange Transport 

Pipeline capacity 

Ormen Lange - Gass ekport fra Nyhamn via Sleipner til Easington (UK) 

Nyhamn exp. press. - Sleipner@151barg Sleipner exp. pressure 42" Sleipner exp. pressure 44" 

Sleipner exp. pressure 46" Sleipner exp. pressure 48" Sleipner press. - Nyhamn@248 barg 

Sleipner press. - Nyhamn@213 barg Sleipner @149 barg 

Easington 73 barg 

10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0 110.0 

Hydraulic capacity, MSm3/d 

42" 

Sleipner pressure 

varying 

42" 42" 

42" 44" 

46" 

48" 

36

System design 

Flow control 

� A single pipeline network system is normally operated on flow control. At the 

upstream end(s) the producing fields or other facilities are often aiming to 

introduce the gas at a steady state. At the downstream end the gas off-take 

may also be at flow control. The pressure in the system is therefore dependent 

on the inventory (packing condition) in the pipeline. If the input to the system 

is less than the output, the system would be de-packed, and the system 

pressure would decrease. By doing this, the system could be operated both in 

packed and de-packed condition, depending on the status of the system. 

37

System design 

Pressure control 

� Because a pipeline system is normally operated on flow control, the pressure 

control system is installed to protect the system against overpressurisation 

(design and maximum incidental pressure). The pressure control system may 

also be used in combination with the flow control system to ensure that the 

pressure is kept above a specified minimum pressure either by contractual or 

technical matters. 

38

System design 

Temperature control 

� The temperature control system is required to protect the pipeline system 

against temperatures above or below the specified design temperatures. The 

maximum design temperature may be reached at the compressor outlet due to 

the pressure increase. The minimum design temperature may be reached due 

to expansion of the gas through the pipeline, valves, etc. 


160 

140 

120 

100 

80 

60 

40 

20 

0 

Sleipner - Easington pipeline, future Sleipner compression 

68M barg 58M barg 48M barg 38M barg 68M Deg C 

58M Deg C 48M Deg C 38M Deg C 

0 100 200 300 400 500 

km from Sleipner 

80 

70 

60 

50 

40 

30 

20 

10 

0 

Temperature, °C 

39

System design 

Metering 

� The gas will be fiscally metered both at the gas inlet and outlet locations. The 

main purpose of the metering system is for tariffs and allocations purposes. 

The system will also be a part of the leak detection system 

40

System design 

Compression and cooling 

� At the compressor outlet, the temperature may be too high to allow the gas 

into the pipeline. The gas is therefore cooled to a temperature below the 

maximum design temperature. The need for a cooling unit downstream the 

compressor is normally determined by the compressor pressure ratio. 

41

System design 

Heating 

� During operation of the pipeline system 

the minimum design temperature may be 

violated due to high utilisation of the 

system or high pressure gradients in parts 

of the system (Joule-Thomson effect). 

During normal operation heating of the 

gas may be required to avoid the 

temperature to drop below the minimum 

design temperature or other limitations 

(sales agreements). In upset situations the 

pressure build-up in parts of the system 

may cause the temperature to drop below 

the minimum design temperature. Heating 

of the gas may therefore be required in 

order to avoid the minimum temperature 

to be violated. 

42

System design 

Gas Quality 

� To avoid deposits in a pipeline and to minimise the possibility of any kind of 

corrosion, including internal stress corrosion, it is essential that the gas 

should conform to the following: 

� The water dew-point, at the working pressure, should at all times be below the 

temperatures of the pipeline. 

� The hydrocarbon dew-point, at the working pressure, should at all times be 

below the temperature of the pipeline – this will also ensure that the calorific 

value of the gas is not reduced by condensation of hydrocarbons. 

� It should be dust-free. 

43

Development solutions move forward 

1970s and 1980s 

2000 

2006 . . . 

44

Kristin 

45

S 

R 

P 

FORE 

Template and 

well slot ID’s: 

S3 S4 

STB PORT 

S2 S1 

R-103/R-201 

FORE 

AFT 

FORE 

N-102/N-201 

N 

S-103/S-201 

S-101 

S-102 

R-101 

R-102 

P-102/P-201 

P-101 

Kristin - Subsea & export field layout 

N-101 

Kristin 

Semi 

Grid North 

P-212 N 

P-212 S 

18” check 

valve with 

1” by pass 

10" ID prod (13% Cr.) w/ DEH 

12" oil export (CS) 

18" gas export (CS) 

Umbilical w/ 2" ID centre line 

3.5“ ID service line (CS) 

Fibre optical cable (FOC) 

Direct el. heating (DEH) risers 

Future tie-in hub 

SSIV 

ROV operated ball valve 

Check valve 

Diverless hot tap tee 

Temporary pig launcher 

P-211 P-211 Oil Oil export export 

Fibre Fibre optical optical cable cable 

Pig Pig direction direction 

P-212 Gas export loop 

Completed well 

Completion ongoing 

Drilled and capped well 

Drilling commenced 

Planned well 

Spare well slot 

Åsgard C 

To Åsgard 

FOC-1/B-401 

16” check 

valve with 

1” by pass 

(ROV op) 

16” 

Åsgard Åsgard Transport Transport P-121 P-121 

Kristin 

Tee 

Size Length Installed 

Tag [mm ID] [Km] Date 

Flowlines: 

N-101 254.0 6.0 

P-101 254.0 6.8 

S-101 254.0 6.0 

S-102 254.0 6.1 

R-101 254.0 6.7 

R-102 254.0 6.7 

Total flowline 38.3 

* excl. riser lengths (640-670 m) 

Service lines: 

N-102 90.6 2.6 

P-102 90.6* 6.4 

S-103 90.6* 5.7 

R-103 90.6 2.0 

Total service line 16.7 

*89.2 in zone 2 

Umbilicals: 

N-201 2.6 

P-201 6.4 

S-201 5.7 

R-201 2.0 

Total umbilical 16.7 

Export pipelines: 

P-211 294.8 22.7 

P-212 411.2 30.0 

Fibre optical cable: 

FOC 26.4 

Structures: 

Template N 23.07.03 

Template P 27.07.03 

Template S 09.05.03 

Template R 26.07.03 

Manifold N 

Manifold P 

Manifold S 

Manifold R 

FRB N-101 

FRB P-101 

FRB S-101 

FRB S-102 

FRB R-101 

FRB R-102 

ERB P-212N 

ERB P-212S 

Template Heading Depth As installed centre positions 

Grid UTM Zone 32 Central Median 9 o E 

N 199.6 o 

368 m E 381 290.05m N 7 214 135.25m 

P 200.6 o 

372 m E 379 280.50m N 7 212 712.38m 

S 181.1 o 

364 m E 378 957.28m N 7 208 585.34m 

R 180.3 o 

Grid UTM Zone 32 Central Median 9 

356 m E 379 050.74m N 7 206 650.42m 

o E 

N 199.6 o 

368 m E 381 290.05m N 7 214 135.25m 

P 200.6 o 

372 m E 379 280.50m N 7 212 712.38m 

S 181.1 o 

364 m E 378 957.28m N 7 208 585.34m 

R 180.3 o 

356 m E 379 050.74m N 7 206 650.42m 

Statoil Kristin Subsea & Export: Schematic field layout 

46 

Drw. No: C074-ZAA-U-XE-0001-04 Date: 180803

Kristin 

Subsea pressure protection 

Subsea PSD System 

PRODUCTION 

MASTER VALVE 

(PMV) 

SCSSV 

PRODUCTION 

WING VALVE 

(PWV) 

(located topside) 

1 

CHOKE 

PTx2 

TO PRODUCTIONMANIFOLD 

2 

HIPPS control logic 

PT (2x) 

(local) 

PT (2x) 

From Manifold Flowline to SSIV 

HIPPS 

VALVE(S) 

SSIV 

Riser PSV 

3 

47

Ormen Lange Concept Screening 

� Gas supply 

� Production profile 

� Build-up and plateau 

� Market scenarios 

� Volume 

� Market opportunities 

� Company based sales 

� Existing infrastructure 

� Platforms 

� Tie-ins and functional requirements 

� Pipelines 

� Capacity and ullage 

� New infrastructure 

48


Nyhamna - Easington 

U.K. 

Easington 

KP 537 

KP 300 

KP KP 350 350 

KP KP 400 400 

KP KP 450 450 

KP KP 500 500 

KP KP 550 550 

Sleipner 

KP 0 

KP KP 625 625 

KP 50 

KP 100 

KP 150 

KP 200 

KP 250 

KP 300 

KP 350 

Sleipner - Easington 42", 537 km 

KP 400 

KP 450 

Nyhamna - Sleipner 42", 625 km 

! ! ! ! 

! ! ! ! 

! 

* 

* 

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!! 

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* 

* 

! 

** 

! 

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! ! 

! 

! 

! ! 

* 

! 

! ! 

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! 

! ! ! !! ! ! ! ! ! 

! ! 

! 

! ! 

* * 

* * 

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! 

! 

! 

! ! 

!! 

! 

! ! 

! !! ! 

Ormen Lange - Nyhamna 2 x 30", 90 km 

ORMEN LANGE 

KP 300 

! ! 

KP KP 100 100 

KP 150 

KP 200 

KP 250 

Nyhamna 

KP 0 

KP 150 

KP 200 

KP 250 

! ! 

! 

! 

KP KP 50 50 

! ! 

! ! 

! 

! 

* 

! 

! ! 

* 

* 

NORWAY 

NORWAY 

! ! 

! ! 

! ! 

* 

* 

! 

! ! 

* 

! ! 

!! ! 

* 

* 

! 

! 

* 

! 

* 

* 

! ! 

* 

! 

! ! 

! 

!! 

DENMARK 

* 

! ! 

* 

* 

! * 

* * 

* 

* 

* 

! 

* 

* 

* 

! 

* 

* 

� Largest pipeline project on the Norwegian 

Continental Shelf 

� The new pipeline will be 1166 km long 

� Large volumes and fast build up profiles 

give an efficient and flexible transportation 

solution 

� Northern leg 

� 42” pipeline with design pressure 215/250 

barg 

� Capacity of 70 – 80 MSm3/d of gas 

� Tie-in to Sleipner Riser plt. 

� Southern leg 

� 44” pipeline with design pressure 156.8 

barg 

� Capacity of 70 - 74 MSm3/d of gas 

49


Nyhamna 

� Nyhamna will include a process and 

export facility with the capacity to send 

a maximum 80 MSm3 gas to market 

daily. The plant will also have storage 

units built into the mountainside and a 

shipping facility for condensate. 

� The untreated wellstream will be 

separated and the gas will go through a 

drying unit before being compressed for 

export. 

50


Sleipner 

� The Ormen Lange Transport will be an 

integrated part of the Norwegian gas 

infrastructure system 

� The connection to Sleipner Riser plt. 

gives flexibility to route gas both to the 

Continent and to the UK 

� Other gas sources than Ormen Lange 

can also supply gas to the UK 

51


Easington 

� Receiving terminal with pressure and 

temperature control (4 process trains) 

� Fiscal metering station 

� Provide a terminal which operates with 

high regularity (99,8%) 

bcm 

160 

140 

120 

100 

80 

60 

40 

20 

0 

2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 

Approved Gas Probable Contracted Imports YTF & Technicals LNG Supply Demand (Wood Mackenzie) 

52

Sleipner as gas centre 

SLA 

SLT 

Kollsnes – Sleipner 70 MSm3/d 

Nyhamna – Sleipner 70 MSm3/d 

Sleipner gas 20 MSm3/d 

Total 160 MSm3/d 

SLR 

53

Sleipner Riser Platform 

Blending services 

WI (MJ/Sm³) 

52.0000 

51.8000 

51.6000 

51.4000 

51.2000 

51.0000 

50.8000 

Wobbe Index 

50.6000 

50 60 70 80 90 100 

Ormen Lange Gas (%) 

OL1-Troll 

OL2-Troll 

OL1-SL 

OL2-SL 

max 

� One of the main advantages of tying in 

Ormen Lange to the Norwegian gas 

network is to allow for quality 

adjustment. The Ormen Lange Wobbe 

Index is rather high, and it may be a 

challenge to meet UK specifications 

without blending with other gas. 

� On the other hand, the Ormen Lange gas 

has a low CO2-content, giving the 

possibility to dilute other Norwegian gas 

to reduce the growing CO2-challenge in 

the gas delivery network: 

� Sleipner gas 

� High CO2 

� Troll gas 

� Low CO2 


� High Wobbe Index 

� Low CO2 

54

Process Flow Diagram 

Sleipner and Ormen Lange Transport 

27-KA01A 

27-KA01B 

26-KA01 

Sleipner T 

Nyhamna 

XV HV 

M 

M 

Injection 

XV EV 

42" 

16" 

EV 

EV560 

20" 

EV 

6 metering 

tubes 

SLA Bridge SLR 

PV169 

16" 

EV171 

16" 

HIPPS 

EV172 

EV990 

20" 

20" 

EV994 

16" 16" 

XV HV HV 

FV XV 

30" 30" 

M 

M 

FV170 

FV197 

M 

XV201 

20" 

XV200 

XV202 

FV138 FV137 

FV 

XV 

M 

M 

XV196 XV195 XV194 

12" 24" 24" 24" 

M 

16" 

EV 

EV 

20" 

20" 

XV088 

XV087 12" HV098 24" 

XV113 

XV114 

24" 

XV151 EV156 

XV141 12" HV186 30" 

44" 

HV136 

EV094 

EV124 

M 

XV 

M 

20" 20" 

40" 

40" 

EV085 

XV 

FV 

EV 

30" 

FV139 

20" 

EV150 

EV180 

EV181 

EV115 

EV182 

HV 

XV 

Easington 

Zeepipe I 

Zeebrugge 

To / from 

Draupner 

Zeepipe II A 

Kollsnes 

XV 

55



Seksjoner med forskjellig design trykk 

250 

206 

200 

150 

100 

50 

System design OLT bypass operation 

DP @ +30MSL MIP @ +30 MSL 65MSm3/d, 206-77 barg 60MSm3/d, 206-105 barg 

60MSm3/d, 191-73 barg PRS Nyhamna PRS Easington 

0 

100 

200 

Operation and 

settle out pressure 

must be 2 bar below 

design pressure 

300 

400 

500 

600 

700 

km from Nyhamna 

800 

900 

1000 

1100 

105 

56



Seksjoner med forskjellig design trykk 

250 

225 

206 

200 

150 

100 

System design OLT bypass operation - PSS-2 

DP @ +30MSL MIP @ +30 MSL PSS-2 225-125 barg SOP PSS-2 

PRS Nyhamna PRS Easington PSS-2 Nyhamna PSS-2 Easington 

0 

100 

200 

300 

400 

500 

600 

700 

km from Nyhamna 

800 

900 

1000 

1100 

125 

105 

57

Wet gas transport 

Snøhvit gas field 

� Snøhvit is planned to come into production 2006 

� Subsea production system transports the multiphase wellstream through a 

143 km long pipeline directly to shore at Melkøya 

� At Melkøya the wellstream 

is separated and the gas 

is cooled to -163 ° C to 

produce LNG 

� LNG shipments by special 

carrier to markets in Europe 

and the USA 

� Liquid production: 

• LNG 

• LPG 

• Condensate 

http://www.statoil.com/snohvit 

58

Snøhvit LNG – Melkøya ved Hammerfest 

59

Water depth relative LAT [m] 

Snøhvit multiphase pipeline - 

Pipeline profile Plem-Melkøya (x/y=km/m) operating window 

40 

-60 

-160 

-260 

-360 

Pipeline elevation profile 

-460 

0 15 30 45 60 75 90 105 120 135 150 

horizontal distance from PLEM [km] 

Liquid content [m3] 

Thousands 

25 

20 

15 

10 

5 

Liquid content in export line 

0 

0 5 10 15 20 25 

Flow rate [MSm3/d] 

35 bar 

70 bar 

60

Snøhvit multiphase pipeline 

Diameter selection – 655 mm ID 

Inlet pressure (bar) 

160 

150 

140 

130 

120 

110 

Snøhvit PLEM pressure - No compression 

5 10 15 20 25 

Flow rate (MSM3/d) 

0.61 

0.63 

0.65 

0.67 

0.68 

0.69 

0.7 

61

Snøhvit multiphase pipeline 

Pipeline system diagram 

Acrobat Document 

62

Statfjord senfase 

63

Natural Gas 

64

Natural gas Dry gas / sales gas - NTNU

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