Primary funding is provided by

The SPE Foundation through member donations

and a contribution from Offshore Europe

The Society is grateful to those companies that allow their

professionals to serve as lecturers

Additional support provided by AIME

Society of Petroleum Engineers

Distinguished Lecturer Programwww.spe.org/dl

David S Hughes

LR Senergy

(davidhughes.spe@btinternet.com)

2014-2015

Society of Petroleum Engineers

Distinguished Lecturer Programwww.spe.org/dl

•2

Offshore CO2 EOR as part of a

National CCS Program:

Opportunities and Challenges

Opening remarks: Geological Storage of

CO2

• New business stream for oil industry

• Store captured liquid/supercritical CO2 in depleted oil and

gas fields and also in saline aquifers

• Synergies with existing operations through reuse of

infrastructure etc. and opportunity to increase hydrocarbon

recovery

• Contributes to the fight on climate change

• Has value through direct sales of CO2 for enhanced oil

recovery (EOR)

• Also through Cap and Trade arrangements or avoidance

of carbon taxes

• But comes with regulations and liabilities

• Uses all our skills

• Worldwide requirement for CO2 emissions reductions

and role of carbon capture and storage (CCS)

• Specific UK targets

• Expected amounts and locations of captured CO2

from national CCS program

• Types and locations of storage sites including estimate

of UK CO2 enhanced oil recovery (EOR) potential

• Planned power plants with CO2 capture (Canada,

USA and UK)

• Challenges of implementing CO2 EOR offshore

• Questions and discussion

Outline of Talk

Worldwide CO2 Equivalent Emissions and

Reduction Requirement

• Emissions reductions pathway consistent with limiting

temperature rise to 2°C (compared to pre-industrial levels)

• 85% reduction in developed countries (1990 baseline)

• 50% reduction overall

Source: Adapted from UNDP, 2007B

iillio

nto

nn

es C

O2

EQ

UIV

AL

EN

Tp

er

ye

ar

Inter-governmental Panel on Climate

Change (IPCC) Fifth Assessment Report

• Table 6.3 from IPCC Working Group III contribution to the

IPCC's Fifth Assessment Report (published April 2014)

• Compares with 445-490 ppm giving likely rise of 2.0-2.4°C

in Fourth Assessment Report (thus 450 ppm target)

• Now probably tolerate ~500 ppm and still limit rise to 2°C

CO2(eq)

concentration in

2100 (ppm)

Temperature

change in 2100

(°C)

430-480 1.5-1.7

480-530 1.7-2.1

530-580 2.0-2.3

580-650 2.3-2.6

650-720 2.6-2.9

720-1000 3.1-3.7

>1000 4.1-4.8

From IPCC Special Report on Carbon Dioxide Capture and Storage 2005 and BP Statistical Review, 2012

IPCC 2005 Prediction of Requirement for

Carbon Capture and Storage (CCS)

• From ~2030 amount of CO2

that requires to be stored

worldwide is ~4 billion

tonnes/year, rising to ~18

billion tonnes/year in 2095

• c.f. 4.0 billion tonnes/year oil

production and 3.0 billion

tonnes oil equivalent/year

gas production in 20112030

Mill

ion

to

nn

es C

O2

p

er

ye

ar

European Union (EU) 2007 Prediction of

Requirement for CCS

• EU prediction suggests requirement for ~3 billion tonnes

per year of CO2 storage

Bill

ion

to

nn

es C

O2

p

er

ye

ar

CO2 Flooding is a Major Enhanced Oil

Recovery (EOR) Process in USA

Also CO2 EOR

opportunity in GOM

to Weyburn and

Midale fields

Kemper Co

Petra Nova

USA CO2 EOR and CO2 Supply

•10

• ~120 projects

• ~300,000 stb/d

• ~75 million tonnes

per year

(CO2 capture)

UK Commitment to Reduction in CO2

Emissions

• Under Kyoto Protocol, UK committed to reducing

greenhouse gas emissions by 12.5% from their 1990

levels by 2012 – actually achieved 25.7% (provisional

figure)

• UK implemented legal requirement for 80% reduction in

1990 emissions by 2050, with interim target of ~34% by

2020

• Capture of CO2 emitted from fossil fuelled power plants

seen as one means of reducing emissions, with geological

CO2 storage in depleted oil and gas fields, and saline

aquifers

Contribution to UK CO2 Emissions From

Power Sector

• UK CO2 emissions 2013

464 million tonnes

• About 1/3 from fossil

fuelled power stations

• Many coal-fired power

stations due to close

• Public opposition to new

coal plants

0

50

100

150

200

250

300

350

400

TW

h/y

ea

r

Coal Coal and Gas CCS Oil Gas Nuclear Renewables Storage

UK Power Generation Prediction by Fuel

(DECC, September 2013)

From DECC – Updated Energy and Emissions Projections 2013, September 2013 (Reference Scenario)

DECC is UK Department of Energy and Climate Change

0

2

4

6

8

10

12

14

16

18

Ca

ptu

red

CO

2 (

millio

n to

nn

es/y

ea

r)

CO2 Captured from CCS in UK Power

Generation Prediction

Derived from DECC – Updated Energy and Emissions Projections 2013, September 2013 (Reference Scenario)

Late 2020s

Average ~12 mill te/y

More Bullish Outlook for CCS in UK from

Energy Technology Institute (ETI)

• ETI predicts 35 million tonnes/year 2025-30

• Rising to 110 million tonnes/year 2035-50

Source: A Picture of CO2 Storage in the UK – learnings from ETI’s UKSAP and derived Projects, ETI, June 2013

ETI is funded by a consortium of industry, and government

ETI Appraisal of Sources and Potential Sinks of

CO2 Around North Sea (Amounts in late 2020s)

Source:

www.co2stored.co.uk

:

10 mill te/y

15 mill te/y

10 mill te/y

0

10

20

30

40

50

60

70

0 25 50 75 100 125 150 175 200 225

Cu

mu

lative

oil (

billio

n s

tock ta

nk b

arr

els

)

Oil field (largest to smallest STOIIP)

Cum STOIIP (billion stb) Cum oil produced (billion stb)

Cum ultimate oil recovery (billion stb)

Some fraction of remaining oil

Say 5 billion barrels

43%

37%

UK Oil Production and the EOR Prize

How does CO2 EOR work?

• CO2 acts as a solvent flushing oil from rock

• Most efficient above the so called minimum miscibility

pressure (MMP)

• CO2 may be more or less dense than the oil, but always

less dense than water

• Efficiency of displacement is limited by heterogeneity and

gravity override

• Expected incremental recovery 5-15% of oil initially in

place

• Between 2 and 5 incremental barrels per net tonne of CO2

injected, but significant recycling of CO2 required

Screening for CO2 EOR Potential

• All 119 UK fields with oil initially in place >100 MMstb

screened (database made available by DECC)

• Screening parameters considered include:

• Ratio operating pressure/CO2 MMP (best <1.2)

• Ratio oil density/CO2 density (0.8-1.2)

• Ratio oil viscosity/CO2 viscosity (<10)

• CO2 efficiency (stb/tonne) (>2)

• Results are aggregated into overall score

• Best candidates, 2nd rank candidates and 3rd rank

candidates identified

• Potential incremental recovery calculated

Estimated Incremental Recovery Potential and

CO2 Stored by Category

• Incremental recovery factors typically 5-12% oil initially in place

• CO2 requirement for individual fields (3% HCPV/y) typically 1 to 4

million tonnes per year

• Leading Operators (best and second rank candidates)

• BP, Apache, Nexen, Talisman and Taqa

Source: PILOT Miscible Gas EOR Workshop, October 2013 (DECC)

Report: Review of UKCS Miscible Flooding and Appraisal of Potential, DECC, September 2013

UK Potential for CO2 EOR

(potential proportional to area of circles)

2 3

9 10

11 12 13 14 15 16

20 21 22 23

28 29 30

42 43 44

47 48 49110

113

204 205 206

210 211

53

54

55

56

57

58

59

60

61

62

-5 -4 -3 -2 -1 0 1 2 3

Latitu

de

Longitude

3rd rank technical candidates 2nd rank technical candidates Best technical candidates Blocks coastline

Early potential candidates

Source: PILOT Miscible Gas EOR Workshop, October 2013 (DECC)

Report: Review of UKCS Miscible Flooding and Appraisal of Potential, DECC, September 2013

Decline in Potential in Operating Fields as Fields

Reach their Cessation of Production Dates

• ~2/3rds of potential is in fields that will have ceased

production by late 2020s

0

500

1000

1500

2000

2500

3000

3500

tota

l

<2

01

3

20

13

20

14

20

15

20

16

20

17

20

18

20

19

20

20

20

21

20

22

20

23

20

24

20

25

20

26

20

27

20

28

20

29

20

30

20

31

20

32

20

33

20

34

20

35

20

36

20

37

20

38

20

39

20

40

20

41

20

42

Incre

me

nta

l Re

co

very

(M

Mstb

)

Best candidates Best and 2nd rank Best, 2nd and 3rd rank candidates

Source: PILOT Miscible Gas EOR Workshop, October 2013 (DECC)

Report: Review of UKCS Miscible Flooding and Appraisal of Potential, DECC, September 2013

0

20000

40000

60000

80000

100000

120000

140000

Yea

r 1

Yea

r 3

Yea

r 5

Yea

r 7

Yea

r 9

Yea

r 11

Yea

r 13

Yea

r 15

Yea

r 17

Yea

r 19

Yea

r 21

Yea

r 23

Yea

r 25

Yea

r 27

Yea

r 29

Yea

r 31

Yea

r 33

Yea

r 35

Yea

r 37

Yea

r 39

Yea

r 41

Yea

r 43

Yea

r 45

Oil

Pro

duction R

ate

(stb

/d)

0%

10%

20%

30%

40%

50%

60%

70%

Recovey F

acto

r (%

)

Oil Production Rate - Waterflood (stb/d)

Oil Production Rate - CO2 Injection (stb/d)

Recovery Factor (%)

Typical CO2 EOR Response in North Sea

Oil Field

0

20000

40000

60000

80000

100000

120000

140000

Yea

r 1

Yea

r 3

Yea

r 5

Yea

r 7

Yea

r 9

Yea

r 11

Yea

r 13

Yea

r 15

Yea

r 17

Yea

r 19

Yea

r 21

Yea

r 23

Yea

r 25

Yea

r 27

Yea

r 29

Yea

r 31

Yea

r 33

Yea

r 35

Yea

r 37

Yea

r 39

Yea

r 41

Yea

r 43

Yea

r 45

Oil

Pro

duction R

ate

(stb

/d)

0%

10%

20%

30%

40%

50%

60%

70%

Recovey F

acto

r (%

)

Oil Production Rate - Waterflood (stb/d)

Oil Production Rate - CO2 Injection (stb/d)

Recovery Factor (%)

Delay?

Typical CO2 EOR Response in North Sea

Oil Field

• Large quantities of offshore CO2 production

(associated with hydrocarbons production)

• Onshore CO2 production from fossil fuelled power

plants

• Need to reduce atmospheric CO2 emissions

• Opportunities

• Inject into oil fields to increase RF by 5-15% OIIP

• Store in depleted gas reservoirs

• Dispose of in saline aquifers

This and following three slides from PRSS Technology Forum

presentation on 26th July 2005 by David Hughes, Senergy

Malaysian Context (offshore PM)

S O U T H

C H I N A

S E A

Kota Bahru

Kuala

Terengganu

Kerteh

JOINTDEVELOPMENT

AREA

K5 (PILONG)

F8(7-B-1)

DAMAR

BINTANG

NORING

LAWIT JERNEH

SEPAT

INASBEDONG

RESAK

BERANANG

DULANG

BUJANGTANGGA BARAT

TANGGA

SEMANGKOK

SEMANGKOKTIMUR

TUJOH

IRONG

TAPISIRONGBARAT

ANGSI

BESAR

SOTONG

MALONG

BERANTAI

DUYONG

BEKOKTIONG

PALAS

TABU

TELOK PENDERA

TINGGI

SELIGI

PULAI BELANGA

ANOA

LEDANGLEDANG BARATPAYONG

KETUMBAR

DELAH

LABA BARAT

BUNGA RAYA

BUNGA MELOR

BUNDI

SOUTH BUNDI

NORTH LUKUT

PENARA

BUBU

LANGAT

KUDA

E & W BELUMUT

PETA KIRI

CHERMINGAT

MESAH

BUNGA PAKMABUNGA ORKID

GAJAH

ULAR

LARUT

LEREK

E. RAYA

RABUNG

LARIS

CAHAYA

OPHIRTEMBIKAI

Kota Bahru

Kuala

Terengganu

Kerteh

JOINTDEVELOPMENT

AREA

K5 (PILONG)

F8(7-B-1)

MERANTI

DULANGTIMUR

SEROKGUNTONG

KEPONG

RHU

PIATU

ABU KECILABU

SERUDON

LAWANG

PETAS. RAYA

EAST PIATU

LARIS

PANTAI

BUNGA KEKWA

(TCOT/GPP)

BUNGA DAHLIA

BUNGA TERATAI

PENINSULAR MALAYSIA

CHENANG

ENGGOR

LEGEND

OIL FIELDS

GAS FIELDS

OIL PIPELINE

GAS PIPELINE

KuantanKuantan

BERTAM

ANDING

DIWANGSA

JAMBU

KAPAL

FERI

Possible offshore

CO2 pipeline

distribution network

(offshore separation)

3-8 million te

CO2/year

From PRSS Technology Forum, 26th July 2005, David Hughes, Senergy

3-8 million te

CO2/year

Malaysian Peninsula - Oil and Gas Fields

Malaysian Peninsula - Power Stations

Possible onshore

CO2 pipeline

system feeding

offshore network

~100 million te

CO2/year

(~15,000 MWe)

From PRSS Technology Forum, 26th July 2005, David Hughes, Senergy

S O U T H

C H I N A

S E A

Kota Bahru

Kuala

Terengganu

Kerteh

JOINTDEVELOPMENT

AREA

K5 (PILONG)

F8(7-B-1)

DAMAR

BINTANG

NORING

LAWIT JERNEH

SEPAT

INASBEDONG

RESAK

BERANANG

DULANG

BUJANGTANGGA BARAT

TANGGA

SEMANGKOK

SEMANGKOKTIMUR

TUJOH

IRONG

TAPISIRONGBARAT

ANGSI

BESAR

SOTONG

MALONG

BERANTAI

DUYONG

BEKOKTIONG

PALAS

TABU

TELOK PENDERA

TINGGI

SELIGI

PULAI BELANGA

ANOA

LEDANGLEDANG BARATPAYONG

KETUMBAR

DELAH

LABA BARAT

BUNGA RAYA

BUNGA MELOR

BUNDI

SOUTH BUNDI

NORTH LUKUT

PENARA

BUBU

LANGAT

KUDA

E & W BELUMUT

PETA KIRI

CHERMINGAT

MESAH

BUNGA PAKMABUNGA ORKID

GAJAH

ULAR

LARUT

LEREK

E. RAYA

RABUNG

LARIS

CAHAYA

OPHIRTEMBIKAI

Kota Bahru

Kuala

Terengganu

Kerteh

JOINTDEVELOPMENT

AREA

K5 (PILONG)

F8(7-B-1)

MERANTI

DULANGTIMUR

SEROKGUNTONG

KEPONG

RHU

PIATU

ABU KECILABU

SERUDON

LAWANG

PETAS. RAYA

EAST PIATU

LARIS

PANTAI

BUNGA KEKWA

(TCOT/GPP)

BUNGA DAHLIA

BUNGA TERATAI

PENINSULAR MALAYSIA

CHENANG

ENGGOR

LEGEND

OIL FIELDS

GAS FIELDS

OIL PIPELINE

GAS PIPELINE

KuantanKuantan

BERTAM

ANDING

DIWANGSA

JAMBU

KAPAL

FERI

Malaysian Peninsula - Oil and Gas Fields

• ~10 billion stb in place

• Ultimate recovery ~3.5-4 billion stb

• CO2 EOR ~0.5-1.5 billion stb

• Requires ~200-650 million te CO2

From PRSS Technology Forum, 26th July 2005, David Hughes, Senergy

Petronas Carigali K5 Gas Field (Offshore

Sarawak)

• GIIP 21 Tscf

• 70 mol% CO2

• Offshore cryogenic distillation

to remove CO2

• 4 Tscf of hydrocarbon gas with

~6.5 mol% CO2 suitable for

LNG processing at Bintulu

• Implies 370 million tonnes CO2

captured

• Saline aquifer storage at depth

of 2.2 km

• Plus CO2 enhanced

hydrocarbon recovery in Block

SK-8, Jintan and Serai fields

• $500 million to $1 billion

• FEED study starting 2015

• Operational 2020

Schematic of Post Combustion Capture Plant

Source:http://www.europeanenergyforum.eu/archives/european-energy-forum/environmental-matters/co2-capture-and-

storage-2013-part-of-the-solution-to-the-climate-change-problem

N2CO2

CO2 removal by

amine adsorption

Flue gas

Source:http://www.europeanenergyforum.eu/archives/european-energy-forum/environmental-matters/co2-capture-and-

storage-2013-part-of-the-solution-to-the-climate-change-problem

Schematic of Pre-combustion Capture Plant

H2O + N2CO2

H2

O2 H2 + CO

H2 + CO2

CO2 removal by

amine adsorption

Gasifier

Power Plant

Conventional

CO2

Capture

Gasification

Reforming

CO2

Capture

Power Plant

Hydrogen-rich fuel

CO2

storage

Power Plant

Oxy-fuel

combustion

Air

Separation

Water

Removal

Post Combustion Capture

Pre-combustion Capture

Oxyfuel Combustion

Coal

Oil

Natural Gas

Water-

Shift

Exhaust, 0.3 - 0.5% CO2

2H2 + O2 2H2O

Exhaust,

0.1 - 0.5% CO2

CH4 + O2 CO2 + 2H2O

H2+CO

H2 for other uses

Capture Options (~90%)

H2+CO2

• Coal 900 kg CO2 per MWh

• Gas 400 kg CO2 per MWh

Gulf of Mexico CO2 EOR Potential

From 2014 Screening Study

Source:CO2-EOR Offshore Resource Assessment, June 2014, DOE/NETL-2014/1631

Gulf of Mexico CO2 EOR Potential

Suggested ‘Anchor’ Fields

Source:CO2-EOR Offshore Resource Assessment, June 2014, DOE/NETL-2014/1631

Proposed Power Plants with CO2 Capture

(selection of projects)

• Canada

• Boundary Dam, Estevan, Saskatchewan, SaskPower, post-combustion retrofit on

139 MW gross, 110 MW net, coal fired station, 1 million tonnes CO2 per year

captured, EOR at Weyburn and aquifer storage (Aquistore project), operational

October 2014

• USA

• Texas Clean Energy Project (TCEP), Penwell, Ector County, Summit Power, pre-

combustion capture at coal IGCC plant, 400 MW gross, 245 MW net, 2-3 million

tonnes CO2 per year captured, EOR in Permian Basin, operational 2019

• FutureGen 2.0, Meredosia, Illinois, FutureGen Alliance (inc. Ameren), retrofit oxy-

combustion at 229 MW coal plant, 1.1 million tonnes CO2 per year captured,

aquifer storage, under construction, operational 2017

• Petra Nova 50/50 JV between NRG Energy and JX Nippon Oil & Gas

Exploration, Unit 8 at the W.A. Parish power plant at Thompsons, near Houston,

post-combustion retrofit on 250 MW (slipstream), coal fired station, 1.4 million

tonnes CO2 per year captured, EOR at the West Ranch oil field, near Vanderbilt

(requires 132 km/82 mile pipeline), construction 2014

• Kemper County IGCC, Mississippi Power, pre-combustion capture (TRIG™

technology, 65% capture) at lignite IGCC plant, 582 MW , 3.5 million tonnes CO2

per year captured, EOR, operational May 2015

Proposed Power Plants with CO2 Capture

(UK Competition Entries for $1.5 billion funding)

• Peterhead, Scotland, Scottish and

Southern Energy and Shell, post-

combustion retrofit on 385 MW gas

fired station, 1 million tonnes CO2

per year captured, 102 km pipeline

to offshore depleted Goldeneye gas

field, final investment decision in

2015, operational 2019

• White Rose, North Yorkshire,

Alstom, Drax & National Grid, new

oxy-combustion coal plant 448 MW,

2 million tonnes CO2 per year

captured, 165 km pipeline to

offshore storage in saline aquifer,

EOR option under consideration,

final investment decision in 2015,

operational 2020

CO2 EOR Onshore - Advantages

• Mature CO2 supply network

• High well density, pattern flood, relatively cheap to

redrill/refurbish

• Relatively low secondary recovery (35-45%)

• Phased implementation

• Large surface area available for facilities

CO2 EOR Offshore - Challenges

• Limited CO2 supply at present but significant quantities

likely to become available on 5-10 year timescale (i.e.

early to mid 2020s)

• Fewer wells, peripheral floods, expensive new wells and

workovers

• High secondary recovery (up to 70%) therefore smaller

target

• Single implementation (i.e. no chance to introduce the

project in phases or to undertake pilot)

• Existing facilities mainly incompatible with high CO2

content in fluids

• Limited weight and space for new facilities

Well Density – Onshore vs. Offshore

• Onshore high well density

• ~2 million barrels per well

• Offshore fewer wells

• ~30 million barrels per well

Offshore CO2 EOR Implementation (Capital

Expenditure)

• Additional ~20 years from existing facilities

• CO2 reception facilities and controls

• Flow lines to injectors (CO2 and water) and

control valves

• Gas/liquid separation facilities capable of

handling high content CO2 in produced

fluids

• Separation of CO2 and hydrocarbon gas (or

just separate enough for fuel gas)

• Dehydration and compression of produced

gas for reinjection (increasing CO2 content

in produced gas)

• Start-up CO2 pumps

• Production well tubing needs replacing with

stainless steel (to deal with produced CO2)

• Baseline measurements for subsequent

monitoring

•Pro

du

ce

dg

as

Assure Storage of Injected CO2 in EOR

Project (to meet regulations)

• Measure amounts injected and

produced to maintain inventory

• Keep average reservoir pressure below

initial pressure

• Assess CO2 seal capacity and seismic

risk over storage period

• Model long-term migrations and

reactions, if any

• Monitor for potential leakage via wells or

geological pathways during injection

period

• Abandon wells in a manner consistent

with long-term secure CO2 storage

Status of Offshore CO2 EOR

• So far only limited application principally re-injecting

natural CO2 or CO2-rich gas, e.g.

• Offshore peninsular Malaysia

• Lula field, Santos Basin, offshore Brazil (SPE 155665)

• Only offshore application using anthropogenic CO2 is in

Rang Dong field, offshore Vietnam (SPE161835 and IEA

EOR Workshops 2009 and 2012)

• Joint Vietnam/Japan venture

• Laboratory studies showed the field a suitable candidate

• Simulation studies indicated potential to increase recovery

by 6.4% of oil initially in place compared with waterflooding

with a utilization efficiency of 3.4 incremental barrels per

tonne of CO2 injected (5.55 Mscf/stb)

• Single well pilot ‘huff and puff’ test undertaken

Rang Dong Field (offshore Vietnam) CO2

EOR Huff and Puff Pilot

• Newly-perfed well section in Lower

Miocene sandstone reservoir

• CO2 sourced from fertilizer plant near

Hanoi

• Trucked by road to Vung Tau (163

tonnes)

• Transported by Ship to Rang Dong

oil field

• 3 stage treatment:

• Establish pre test flow rate then log

saturation profile (RST)

• Inject CO2 (111 tonnes), leave to ‘soak’

then log

• Flow well then log

Result – Simulation vs. Actual

• 111 tonnes CO2 injected (2.1 MMscf) over 7 hours followed by soak

• BHP ~3300 psia, MMP 2980 psia

• Swelling and viscosity reduction mechanisms observed

• Oil rate increased from 950 to 1500 stb/d

• Watercut reduced from 50-60% to near zero

• 214 incremental stb of oil

• Utilization 1.9 incremental stb per tonne of CO2 (or 9.8 Mscf/stb)

• Pre and post injection logging indicates saturation reduction

To conclude: So what does the future hold

for CO2 EOR in the North Sea?

• Supply of CO2 will (in all probability) develop from national

CCS program

• Initial CCS projects will plan for storage only, but proximity and

availability of CO2 likely to provide opportunities for EOR

initially possibly in the smaller/medium sized fields

• If successful, redevelopment of larger mature fields may occur

• New specialist CO2 operators may emerge

• Once EOR phase complete some extra opportunity to store

additional CO2

• Adjustment of tax regime may be needed to make offshore

EOR economic

• Regulation around CO2 storage (over and above O&G

regulations) may be a significant burden

Big Decision

• Bulk of CO2 captured in

south (2035-50 numbers

from ETI)

• Saline aquifer storage

nearby

• but EOR opportunity in

oil fields in north

• Trunk pipeline required

• Who should pay?

• Up to £1 billion? 95 mill te/y

15 mill te/y

Source: www.co2stored.co.uk

• That concludes my presentation

• Thanks to the SPE Distinguished Lecturer program for

sponsoring my visit here today

• Also to my employer LR Senergy (www.lr-senergy.com)

for allowing me to give these presentations

• Any questions?

Questions

Society of Petroleum Engineers

Distinguished Lecturer Programwww.spe.org/dl •48

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