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NON

NON

-

-

PIPELINE TRANSPORT OF

PIPELINE TRANSPORT OF

NATURAL GAS

NATURAL GAS

Jón Steinar Gudmundsson

TPG4140 NATURGASS

NTNU

September 16, 2010

(2)

Associated

Associated

Gas Problem

Gas Problem

World-wide, oil fields cannot be developed

unless the associated gas problem can be

solved (”stranded oil”)

The term ”stranded gas” is used in situations

where the oil/gas field is remote or located in

deep water

The term ”marginal gas” is used in situations

where the oil/gas field is too small to justify a

gas pipeline

(3)

Associated

Associated

Gas Solutions

Gas Solutions

Gas-to-Flare (burning)

Gas-to-Well (injection)

Gas-to-Liquid (LNG, MOH etc.)

Gas-to-Wire (electricity)

Gas-to-Tank (CNG)

(4)

Non

Non

-

-

Pipeline

Pipeline

Technologies

Technologies

CNG

Compressed Natural Gas

GTL

Gas-to-Liquid (incl. MOH)

GTW

Gas-to-Wire (DC and AC)

LNG

Liqufied Natural Gas

(5)

CAPACITY

CAPACITY

-

-

DISTANCE DIAGRAM

DISTANCE DIAGRAM

Gudmundsson and Mork (2001)

Gudmundsson and Mork (2001)

0,1 1,0 10,0 100 1000 10000 Distance (km) C a p a c ity (B C M /y e a r) PIPE LNG CNG, GTW, NGH GTL ALL

(6)

Quick Chemistry Lesson

Quick Chemistry Lesson

Methanol

CH

4

+ H

2

O (steam)

 CO + 3H

2

CO + 2H

2

 CH

3

OH

Ammonia

CH

4

+ H

2

O (steam)

 CO

2

+ H

2

3H

2

+ N

2

 2NH

3

Urea

2NH

3

+ CO

2

 CO(NH

2

)

2

+ H

2

O

(7)

Size

Size

and Technology

and Technology

Hove et al. (1999) Hove et al. (1999)

0.38 TCF

1.6 MSm3/d

NGH

0.54 TCF

2500 MTPD

MOH

1.36 TCF

20,000 bbl/d

Syncrude

2.75 TCF

3 MTPY

LNG

Field

Size

Nominal Plant

Capacity

Non-Pipeline

Technology

(8)

Norwegian

Norwegian

Fields and Plants

Fields and Plants

20 BCM/year

4.3 BCM/year

400 BCM

(=14.1 TCF)

190 BCM

(=6.7 TCF) 1 Sm3 = 35.314 ft3

Ormen Lange

Hammerfest LNG*

Plant Size

(gas prod.)

Reserves

(gas, LPG, cond.)

Field Name

* Feed flow 6.9 BCM/year, Products 6.0 BCM/year,

(9)

Natural Gas Resources

Natural Gas Resources

BP (2001) and Hove et al. (1999)

BP (2001) and Hove et al. (1999)

World reserves 150 TCM (=5295 TCF)

38% in FSU, 35% Middle East, 9% OECD

and 18% other regions

80% new gas fields less than 0.25 TCF

(=7 BCM) in size

Assuming 20 years, gives delivery

(10)

Natural Gas

Natural Gas

Monetisation

Monetisation

Routes

Routes

5 TCF

5 TCF

field

field

size

size

, 600

, 600

MMscfd

MMscfd

(=6.2

(=6.2

BCM/year

BCM/year

)

)

Klein

Klein NagervoortNagervoort (2000)(2000)

0.1% 3 MTPA 3,000 MTPA GTL 4% 4 MTPA 100 MTPA LNG 20% 6 MTPA 30 MTPA (corrected) MOH Plant % Global Demand Plant Size Global Demand Non-Pipeline Technology

(11)

Shell

Shell

Middle

Middle

Distillate

Distillate

Synthesis

Synthesis

Process

Process

Klein

(12)

FPSO

FPSO

Overview of Alternatives

Overview of Alternatives

(13)

FPSO

FPSO

+

+

Methanol

Methanol

(14)

FPSO +

FPSO +

Methanol

Methanol

Stabilisation/ Distillation Methanol Synthesis Choke Manifold Separation Desulphur-isation TCR reforming Steam Produced water

treatment Crude Oil Storage tanks Methanol Storage tanks

To shuttle Tanker Oil Water Gas Gas Crude oil Water Discharge

(15)

Process, Marine CNG

Process, Marine CNG

Discharge - $5%

Load - $10%

54 bar 27 oC compress refrigerate 200 bar 10 oC 200 bar 5 oC 10 ba r -30 oC expand scavenge heat 15.5 knots 47 bar 5 oC

Sail - $85%

(16)

Pipe, CNG and LNG, 400

Pipe, CNG and LNG, 400

MMscfd

MMscfd

0.00 0.50 1.00 1.50 2.00 2.50 3.00 0 500 1000 1500 2000 2500 3000 Distance, Kilometers T a ri ff, $ /m m B tu LNG One Train CNG Achievable Tech Ship 1 Ship 3 Ship 2 Ship 1

Compression & Marine

Ship 2

Ship 10

Continental Shelf Pipeline

(17)

Pipe vs. CNG

Pipe vs. CNG

0.00 0.50 1.00 1.50 2.00 2.50 3.00 3.50 4.00 4.50 0 2 4 6 8 10 12

DCQ bcmy

T

a

ri

ff, $

/m

m

B

tu

$55,000 per dia.inch.mi, 900 miles

No intermediate compressor stations

Standard CNG Carriers (Cons)

4

30" pipeline

5

(18)

Hydrate

Hydrate

E

E

quilibrium

quilibrium

C

C

urve

urve

0 20 40 60 80 100 120 140 160 180 200 0 5 10 15 20 25 Temperature [°C] P ressu re [b ar ] Natural gas Methane 180 Sm3 of gas 1 m3 of hydrate

(19)

Chain LN G N G H D ifference

Production 1220 (51% ) 792 (44% ) 428 (35% )

Carriers 750 (32% ) 704 (39% ) 46 (6% )

R egasification 400 (17% ) 317 (17% ) 83 (21% )

Total 2370 (100% ) 1813 (100% ) 557 (24% )

Capital cost of NGH and LNG chains for 400

Capital cost of NGH and LNG chains for 400 MMscf/dMMscf/d production and production and transport over 3500 nautical miles. Million US dollars mid

(20)

PIPE, GTL, LNG, NGH

PIPE, GTL, LNG, NGH

Capex

(21)

NGH Slurry on FPSO

(22)

NGH Slurry on FPSO

NGH Slurry on FPSO

Process Flow Diagram

(23)

NGH on FPSO

NGH on FPSO

Transport Cost vs. Distance

Transport Cost vs. Distance

Hove et al. (1999)

(24)

CONCLUSIONS

1. There is a need for non-pipeline technologies that can capture stranded gas and transport to market. NGH technology is being developed for this purpose and is increasingly recognised as an attractive alternative.

Several groups are developing NGH technology world-wide, including NTNU in Norway.

2. LNG technology is recognised as the technology of choice for

large-volume, long-distance transport of natural gas. However, about 80% of the natural gas resources yet to be developed world-wide are too small for state-of-the-art LNG technology and about one-half of these (40% of total) are stranded.

3. The cost of transporting stranded gas to market using non-pipeline technologies has been estimated in the range 1.5 to 3.0 US$ per million BTU (ca. 1.5-3.0 US$/GJ), depending on scale of development and distance to market. CNG and NGH are competing in similar stranded gas situations.

References

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