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Copyright of COMPANY NAME
THE PETERHEADCARBON CAPTUREAND STORAGE PROJECT
UP HERE TOO MUCHCO2 IS A PROBLEM
DEEP DOWN UNDERTHE NORTH SEATHERE IS A SOLUTION
Copyright of SHELL UK
PETERHEAD CCSCO2 INJECTION INTO A DEPLETED RESERVOIR
Luis Acevedo, Owain TuckerShell UK
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Copyright of SHELL UK
CAUTIONARY STATEMENT
The companies in which Royal Dutch Shell plc directly and indirectly owns investments are separate entities. In this presentation “Shell”, “Shell group” and “Royal Dutch Shell” are sometimes used for convenience where references are made to Royal Dutch Shell plc and its subsidiaries in general. Likewise, the words “we”, “us” and “our” are also used to refer to subsidiaries in general or to those who work for them. These expressions are also used where no useful purpose is served by identifying the particular company or companies. ‘‘Subsidiaries’’, “Shell subsidiaries” and “Shell companies” as used in this presentation refer to companies in which Royal Dutch Shell either directly or indirectly has control. Companies over which Shell has joint control are generally referred to as “joint ventures” and companies over which Shell has significant influence but neither control nor joint control are referred to as “associates”. The term “Shell interest” is used for convenience to indicate the direct and/or indirect ownership interest held by Shell in a venture, partnership or company, after exclusion of all third-party interest.
This presentation contains forward-looking statements concerning the financial condition, results of operations and businesses of Royal Dutch Shell. All statements other than statements of historical fact are, or may be deemed to be, forward-looking statements. Forward-looking statements are statements of future expectations that are based on management’s current expectations and assumptions and involve known and unknown risks and uncertainties that could cause actual results, performance or events to differ materially from those expressed or implied in these statements. Forward-looking statements include, among other things, statements concerning the potential exposure of Royal Dutch Shell to market risks and statements expressing management’s expectations, beliefs, estimates, forecasts, projections and assumptions. These forward-looking statements are identified by their use of terms and phrases such as ‘‘anticipate’’, ‘‘believe’’, ‘‘could’’, ‘‘estimate’’, ‘‘expect’’, ‘‘goals’’, ‘‘intend’’, ‘‘may’’, ‘‘objectives’’, ‘‘outlook’’, ‘‘plan’’, ‘‘probably’’, ‘‘project’’, ‘‘risks’’, “schedule”, ‘‘seek’’, ‘‘should’’, ‘‘target’’, ‘‘will’’ and similar terms and phrases. There are a number of factors that could affect the future operations of Royal Dutch Shell and could cause those results to differ materially from those expressed in the forward-looking statements included in this presentation, including (without limitation): (a) price fluctuations in crude oil and natural gas; (b) changes in demand for Shell’s products; (c) currency fluctuations; (d) drilling and production results; (e) reserves estimates; (f) loss of market share and industry competition; (g) environmental and physical risks; (h) risks associated with the identification of suitable potential acquisition properties and targets, and successful negotiation and completion of such transactions; (i) the risk of doing business in developing countries and countries subject to international sanctions; (j) legislative, fiscal and regulatory developments including regulatory measures addressing climate change; (k) economic and financial market conditions in various countries and regions; (l) political risks, including the risks of expropriation and renegotiation of the terms of contracts with governmental entities, delays or advancements in the approval of projects and delays in the reimbursement for shared costs; and (m) changes in trading conditions. All forward-looking statements contained in this presentation are expressly qualified in their entirety by the cautionary statements contained or referred to in this section. Readers should not place undue reliance on forward-looking statements. Additional risk factors that may affect future results are contained in Royal Dutch Shell’s 20-F for the year ended December 31, 2014 (available at www.shell.com/investor and www.sec.gov ). These risk factors also expressly qualify all forward looking statements contained in this presentation and should be considered by the reader. Each forward-looking statement speaks only as of the date of this presentation, May 21, 2015. Neither Royal Dutch Shell plc nor any of its subsidiaries undertake any obligation to publicly update or revise any forward-looking statement as a result of new information, future events or other information. In light of these risks, results could differ materially from those stated, implied or inferred from the forward-looking statements contained in this presentation.
We may have used certain terms, such as resources, in this presentation that United States Securities and Exchange Commission (SEC) strictly prohibits us from including in our filings with the SEC. U.S. Investors are urged to consider closely the disclosure in our Form 20-F, File No 1-32575, available on the SEC website www.sec.gov. You can also obtain these forms from the SEC by calling 1-800-SEC-0330
3March 16, 2015
Copyright of SHELL UK
AGENDA
Project Introduction
CO2 Properties
Well Concept
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Copyright Reserved. 5
PETERHEAD CCS - SUMMARY
CO2 capture volume: 10 to 15 million tonnes over a period of 10 to 15 years
High Purity CO2 - 50 ppmv H2O, 1 ppm O2
CO2 transported via combination of existing and new pipelines to Goldeneye field for storage
Operated in dense phase
Arrival at platform at seabed conditions: ~120bar, 4°C
Copyright of Shell U.K. Ltd. 6
EXISTING GOLDENEYE PLATFORM AND WELLS
Unmanned Installation
5 wells drilled 2003/04, COP 2011
Res. temp. 83°C
Res. P - Hydrostatic
Minimum 0.25psi/ft, Current P 0.32psi/ft
7” existing upper completion
Copyright of SHELL UK
CO2 PHASE BEHAVIOUR
Pre
ssure
(Psi)
725
1450
2175
2900
Copyright of SHELL UK
INJECTION INTO A DEPLETED RESERVOIR
Reservoir
Depleted hydrocarbon
Aquifer presence
8
0
10
20
30
40
50
60
70
2000 2500 3000 3500 4000
CIT
HP,
ba
r
Preservoir, psi
CITHP vs Preservoir(Geothermal Gradient)
Copyright of SHELL UK
INJECTION - FREE CO2 EXPANSION
9
Current Completion Steady state flow at 2500psi
-2605.00
-2175.00
-1745.00
-1315.00
-885.00
-455.00
-25.00
-30.00 -20.00 -10.00 0.00 10.00 20.00
Temperature (Deg C)
TV
D (
m)
2500psi_57MMscfd 2750psi_57MMscfd 3000Psi_57MMscfd
3500psi_57MMscfd 3800psi_57MMscfd
• This low temperatures will create issues in existing wells (low temperature, wellhead)
P reservoir
Copyright of SHELL UK
EXISTING COMPLETIONS NEEDED TO BE WORKED OVER
The existing completion (7”) under steady state injection needed to be replaced because:
Expansion of CO2 in the 7” tubing could cause low temperatures (below some well elements threshold)
Polished Bore Receptacle (PBR) was unsuited to new service
Alternatives like warming up CO2 precluded owing to remote normally unmanned platform
Solution – work over the wells to manage the CO2 phase behaviour
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Copyright of SHELL UK
THE SOLUTION – KEEP CO2 IN DENSE PHASE
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0
20
40
60
80
100
120
-40 -20 0 20 40
Pre
ssure
, bar
Temperature, °C
Expected Wellhead expansion
CO2 Saturation Line
Isenthalpic - JT
Pipeline Conditions
Critical Point31 °C, 73.8bar
Liquid
Gas
Keep CO2 in liquid phase Minimum Rate
Copyright of SHELL UK
VLP - TUBING SIZE SENSITIVITY
12
2000
2500
3000
3500
4000
4500
5000
5500
0 10 20 30 40 50 60 70 80Inje
ctio
n B
ott
om
Ho
le P
ress
ure
, psi
Injection Rate, MMscfd
Tubing Size Sensitivity(Based on GYA01 well)
Inflow - P reservoir 2650psi Inflow - P reservoir 3450psi
5.5" tubing 50bar 5.5" tubing 115bar
4.5" tubing 50bar 4.5" tubing 115bar
3.5" tubing 50bar 3.5" tubing 115bar
2 7/8" tubing 50bar 2 7/8" tubing 115bar
CCP Rate
2 7/8" tubing 3 1/2" tubing
4 1/
2" t
ub
ing
5 1/
2" t
ub
ing
Copyright of SHELL UK
VLP – P/T TRAVERSE IN THE WELL
130
50
100
150
200
250
300
-30 -20 -10 0 10 20 30 40 50 60 70 80 90 100
Pre
ss
ure
, b
ar
Temperature, °C
CO2 Density and Injection Conditions
100 Kg/m3
200 Kg/m3
300 Kg/m3
400 Kg/m3
500 Kg/m3
600 Kg/m3
700 Kg/m3
800 Kg/m3
900 Kg/m3
1000 Kg/m3
Saturation
Wellhead conditionsBottomhole
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
0 50 100 150 200 250 300
True
Ver
tica
l Dep
th,
ftPressure, bar
Pressure Traverse
41 MMScfd 50bar FTHP 41 MMScfd 80bar FTHP 41 MMScfd 115bar FTHP
63 MMScfd 50bar FTHP 63 MMScfd 80bar FTHP 63 MMScfd 115bar FTHP
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
0 10 20 30 40
True
Ver
tica
l Dep
th,
ft
Temperature, °C
Temperature Traverse
41 MMScfd 50bar FTHP 41 MMScfd 80bar FTHP 41 MMScfd 115bar FTHP
63 MMScfd 50bar FTHP 63 MMScfd 80bar FTHP 63 MMScfd 115bar FTHP
Copyright of SHELL UK
WELL OPERATIONS – OPEN / CLOSE THE WELLS
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Steady State CO2 Injection (All Dense)
WHP = Inj. Pressure
Well Just Closed-In (2 Phases)
WHP < CITHP
CO2 Flashing (No friction and Low Pres)
Well Closed-In for a long time (2 Phases)
WHP = CITHP
Dense CO2
Gas CO2
Wellhead Choke Closed
Wellhead Choke Open
Steady State Transient State
Well Close in
Well Start Up
Injection Fluid TempAvg. tubing temp
Avg Prod Casing temp
WH PressureGas Mass Flow
Well Design Case (2h CI, 2h SU) –
1 DegC (downstream of choke) (45bar THP) Injection fluid temp
2500 psi
Copyright of SHELL UK
CONCLUSIONS
Existing wells can be used for CCS
Depleted reservoir poses some extra challenges from the CO2 phase behaviour perspective
Flow assurance pipeline-wells important
Well concept of using small tubing
Can design system to eliminate steady state expansion
Trade off: restrictions in terms of minimum rate
Management of transients
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