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TRANSCRIPT
Building an Enhanced Oil Recovery Culture to Maximise
Asset Value
Marco Rotondi Stavanger, 28th April 2015
EOR Mindset
EOR Costs
Building an Enhanced Oil Recovery Culture: Action Plan
EOR Challenges & Solutions
eni Successful Case Histories
Introduction
3
2
4
1
Building an Enhanced Oil Recovery Culture - Agenda
2
2.2
EOR Time to Market 2.1
2.3
Conclusions 5
Meeting Future Production Demand
3
EOR Introduction
1970 1980 1990 2000 2010 2020 2030
Mill
ion
Bar
rels
Per
Day
0
25
50
75
100
Natural depletion
IOR
EOR
Unconventional
Deepwater & complex environment
Source: IEA World Energy Outlook 2012
EOR 3% 8% 24%
Microbial Methods & Others
Chemical Injection
Thermal Methods
Miscible Gas Injection & WAG
Enhanced Oil Recovery
Global oil demand
EOR Projects Time to Market
4
Faster Deployments
Lab Analyses & Simulation Screening Phase
Y1 Y3 Y4
Pilot Test @ well scale
Interwell Pilot Test
Y5
Full Field Implementation
Y6-8
EOR Challenges
Lab Analyses & Simulation
Screening Phase
Pilot @ well
Interwell Pilot Test
Full Field Implementation
From a sequential to a quicker parallel approach
§ EOROGTM
§ IPSE § in-house EOR labs
§ APA for EOR § Streamlines § High Resolution Simulator
§ Log-inj-log § SWCTT
§ Standard procedures § Strategic contracts § Monitoring best practices
WA SWCTT (Jan 2014)
NA SWCTT (Aug 2014)
NA Polymer Plant (2014)
NA Polymer Plant (2015)
5
Screening Tool for Optimal EOR Techniques & Analogues
CO2 MISCWAG CO2 MISC
HC MISC
WAG HC IMM
WAG HC MISC
polymer
surfactant
Magnus
CO2 Immiscible
CO2 Miscible
WAG CO2 Miscible
HC Miscible
WAG HC Miscible
N2 Miscible
Polymer
Surfactant
Algorithm searches for analogues within EOR database Optimal EOR Techniques List of references 1 2 3
1) “Development and Testing of Advanced Methods for the Screening of EOR Techniques” – EAGE IOR Symposium, April 2015 2) SPE-174315 – “A New Bayesian Approach for Analogs Evaluation in Advanced EOR Screening” – EUROPEC, June 2015
EOR Challenges
In house tool for quick screening phase and EOR analogues evaluation
6
Understanding & Reproducing EOR Mechanisms
Production Data Analysis for EOR
Material Balance
Streamlines
1
2
3
EOR Challenges
Janus Bifrons
3D simulation
§ Core Scale
§ Well Scale (SWCTT)
§ Sector & Full Field Scale
4
Coreflood N.1: High and Low Salinity Water
0
5
10
15
20
25
30
35
40
45
50
0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52
time (hours)
oil r
ecov
ery
(%)
measured
STARS
Eclipse 100
UTCHEM
Eclipse Stars
UTChem
“Study the past if you would divine the future”
Optimizing Waterflood
Methane Bank
Faster & More Accurate EOR Simulations
7
Deployment of a high resolution simulator for full field simulation
Standard Case Study § Low permeability oil reservoir § Coarse grid: 139x122x56, 200k active cells § 46 Horizontal wells and LGR to simulate
horizontal wells + hydraulic fractures
Elapsed Time - Coarse Model
More accuracy, more simulations, additional time for res eng -> more solutions 1) SPE171965 – “Deployment of High-Resolution Reservoir Simulator: Methodology & Cases” – ADIPEC, Nov. 2014 2) http://www.slb.com/resources/case_studies/software/cs_eni_intersect.aspx 3) SPE175633 “Advances in Sim. Tech. for High-Resolution Models: Achievements & Opp. For Improvement”- SPE RCSC Sept. 2015
EOR Challenges
old simulator 15h
new simulator 12 min!
Pushing the limits § Combining HPC2 hardware (30,000 cores, 6000 GPUs) and new simulator to run larger models and
capture geological complexity avoiding upscaling
eni Green Data Center 240M cell model
Outstanding results in terms of simulation time
Reducing EOR Costs
8
EOR Challenges
Sources: Resources to Reserves, IEA – 2013 World Energy Investment, IEA – 2014
MENA
Conv.Oil
EOR
Arctic
AlreadyProduced
Heavy Oil T
igh
t O
ilU
DW Oil Shale GT
L
CT
L
Finding & Development costs @ 2035
Oil Production Costs § EOR generally perceived as
expensive, but comparable
production costs to other oil
resource exploitation
§ Finding & development
costs even lower if projected to
2035
§ Keep an eye on emerging
techniques
§ Low Salinity & ‘Smart’ Water
§ Considering existing surface
facilities & infrastructures
and seek for opportunities!
EOR… § is still wrongly perceived as a “reservoir or lab” subject while requires a fully
multidisciplinary approach § is still considered a technological frontier: “We have always done like this…” § should not be exclusive to mature fields § requires a strong top management support and long term vision / continuity
9
EOR Challenges Changing the Mindset – A new EOR ‘Culture’
EOR know-how dissemination
(WS, webinars, lectures, papers, etc.)
Internal guidelines & external collaborations
Reorganization and reinforced EOR team
Growing of a new generation of EOR professionals to generate new
ideas and support future EOR
implementations
start
EOR Systematic Screening & Opportunity Evaluation
10
EOR Action Plan
§ Many valuable studies and lab tests, very few field applications § More time spent to understand “how it works” rather than “if it works in the field” § A more pragmatic approach was needed to promote EOR applications within the
Company § Reorganising and rationalising EOR initiatives and R&D portfolio
EOR Systematic Screening & Opportunity Evaluation
11
EOR Action Plan
Miscible GI & WAG
Low Salinity
Chemical EOR
Others
Evaluation of additional unconstrained EOR resources & RF
Additional
EOR oil
2 3 Optimal EOR Techniques
(Strategy revision) eni Portfolio Screening
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
10000
11000
12000
13000
14000
15000
16000
17000
18000
19000
20000
0,1 1 10 100 1000 10000
Dep
th (
ft)
Viscosity (cP @RC)
Thermal
Polymer ASP
mGI Low Salinity
iGI
Oil field
1
Hig
h L
evel
Scr
een
ing
S
econ
d L
evel
Scr
een
ing
eni Field Analog Field
Current Dev MGI+WI
Porosity 14 %
Permeability 200 mD
Depth 8760 ft
MMP 3500 psia
Viscosity
Temperature 185 °F
Initial Pressure
OOIP
RF@2014
Current Dev WAG
Porosity 14 %
Permeability 243 mD
Depth 9840 ft
MMP 3002 psia
Viscosity
Temperature 207 °F
Initial Pressure
OOIP
RF@2014
4 Field by field opportunity evaluation (analogues)
Mid term opportunity implementations (building internal
competences)
Short term opportunity implementations
(quick deployment of mature techniques at low cost)
5b
5a
WAG
CEOR
eni EOR Projects
1) WAG 2) Polymer 3) Surfactant Polymer 4) Electrical Heating
Steam
CO2 Low Salinity + Polymer flooding
1) Polymer flooding 2) Low Salinity + Polymer 3) Bright Water
GI+mWAG
iWAG & FAWAG
GI
Pilot Study Full field implementation
Bright water + low salinity
GI
Thermal EOR Gas injection Chemical EOR
More than 20 new EOR initiatives launched…
12
EOR Action Plan
iWAG
Miscible WAG – Pushing RF
§ Onshore NA field § Developed with WI and mGI § Already high RF
§ Nearby field produced by means of WAG § New reservoir model
§ Conversion of existing WIs § WAG pilot started in Q2 2013 § Impressive results, additional URF of 6%
§ Cost per EOR barrel < 0,5 USD/stb
EOR Case Studies
eni Field Analog Field
Current Dev MGI+WI
Porosity 14 %
Permeability 200 mD
Depth 8760 ft
MMP 3500 psia
Viscosity
Temperature 185 °F
Initial Pressure
OOIP
RF@2014
Current Dev WAG
Porosity 14 %
Permeability 243 mD
Depth 9840 ft
MMP 3002 psia
Viscosity
Temperature 207 °F
Initial Pressure
OOIP
RF@2014
North Africa mWAG Overview
WAG1
WAG2
Prod1
07/2009 06/2010 06/2011 05/2012 05/2013 04/2014 04/2015 03/2016
Qo
il [S
TB
/d
]
Prod1 WAG1 Start-up
WAG gain
Higher than initial plateau
Improving RF: Never give up! SPE174700, "On the Road to 60% Oil Recovery By Implementing Miscible HC WAG Injection in a NA Field” – SPE EORC, Aug. 2015 13
Downdip Immiscible WAG
§ Offshore UK, structurally complex reservoir § Developed with WI (high WC = 91%) & crestal offspec gas disposal § Change of operatorship in April 2014 -> APA, Streamline, New 3D Model § Water injection is inefficient and attic oil bypassed § WAG a feasible solution -> gas from issue to resource
§ WAG Pilot (conversion of two water injectors) foreseen for Q2/Q3 2015
§ Low cost opportunity
§ Additional 2% on URF § Based on pilot results, other 3 water injector wells will be
converted to WAG injectors
WAG forecasts
UK iWAG Overview
EOR Case Studies
attic oil
water path
From study to pilot in 1y time, low cost per EOR barrel 14
0
1000
2000
3000
4000
5000
6000
01/2015 12/2018 12/2022 12/2026 12/2030
Oil
Rat
e
WAG pilot
Deepwater iWAG & Foam Assisted WAG Implementing EOR from Day 1
§ Deepwater WA field
§ Production start-up Q1 2015 (2 prod)
§ iWAG start-up Q2 2015 (2 inj)
§ Analogue field produced by WAG showed gas BT in 1.6 km away producer in 75 dd
§ FAWAG R&D project launched
Project Overview
WAG & FAWAG Forecasts
EOR Case Studies
§ Foam Assisted WAG is aimed at:
§ Reducing gas mobility in reservoir
§ Increasing sweep efficiency
1 3 5 7 9 11 13 15
Oil
Rat
e
FAWAGWAGNatural Depletion
GO
R
WI WAG
Surfactant Injection
years
WAGFAWAG
After 7 years of injection
OP1WAG2
WAG FAWAG
OP1WAG2
0.03
0.5
0.9§ WAG + 30% on RF
wrt natural depletion
§ FAWAG less than 1% on additional recovery but – 53% on produced gas
Moving to more complex techniques to maximise RF & mitigate subsurface risks 15
Maximising Sweep Efficiency in Waterfloodings
16
Lab Analyses & Simulation Screening Phase Pilot Test @
well scale Interwell Pilot
Test Full Field
Implementation
§ 2 NA Low Salinity Projects § Alaska Low Sal + Polymer § ME low salinity § WA offshore polymer
§ Egypt Bright Water § NA Polymer flooding § NA Low Salinity + Polymer flooding
WA SWCTT (Jan 2014) NA Polymer Plant (2014)
EOR Case Studies
1) SPE171794 – “Low Salinity Water Injection: eni’s Experience” – ADIPEC, 2014 2) SPE17951 – “SWCTT to Assess Low Salinity Water and Surfactant EOR Processes in West Africa” – IPTC, 2014 3) “Low Salinity Waterflooding for EOR: Stochastic Model Calibration and Uncertainty Quantification” – EAGE IOR 2015
Exploiting & combining water
conformance, low salinity &
chemical EOR techniques
WA Low Sal+Surfactant SWCTT (Jan 2014)
NA Low Salinity SWCTT (Aug 2014)
§ Tunisia BW
Areal sweep efficiency
Vertical Sweep
Efficiency
Microscopic Displacement
Water Conformance
oilwater
sandgrain
~ 10-4 m
inje
ctor
prod
ucer
Polymer Flooding
Low Salinity
Surfactant
§ Thermally activated polymer that improves waterflooding sweep efficiency by in depth reservoir conformance i.e. plugging thief zones and forcing water to follow new paths
§ Ultra mature field, 94% WC § Target bypassed oil (inefficient WI by APA & Streamline analysis) § 2010: successful pilot test § 2013: extension to 2 water injectors and 7 producers
Bright Water Pilot & Field Deployment Results
Bright Water Deployment
Field Results
+60 kstb
+130 kstb
Extension Pilot
EOR Case Studies
SPE154042 – “Thermally Activated Particle Treatment to Improve Sweep Efficiency: Pilot Test Results and Field Scale Application Design in El Borma Field” – IOR Symposium, April 2012 17
Well A (Pilot) Well B
Bright Water Field Deployment Results
EOR Case Studies
Well C Well D
Gain continuing with time, well life extension > 5y, Low treatment costs
18
North Africa Polymer Flooding Pilot
EOR Case Studies
19
Polymer Plant
“Polymer Injection: EOR Application in a North African field from Lab Analyses to Project Start-up”, OMC 2015
0
20
40
60
80
100
120
0
10
20
30
40
50
60
70
80
90
100
Rat
e [b
bl/d
ay]
WC
T [%
]
Liquid Oil
0
10
20
30
40
50
60
70
80
90
100
WC
T [%
]
Polymer Inj.
Increase in oil production (Well A)
Polymer Inj.
WCT reduction (Well B)
North Africa – Maximising Waterflooding Efficiency
EOR Case Studies
20
23 average
18 average
14 max
0
5
10
15
20
25
30
sea water low salinity
So
rw (
%)
SWCTT - Results
Oil Gain +38%
BW Results
3 monthswater
preflush
1st polymerslug 3 cP
2nd polymer slug6 cP in Low Sal Water drive
Dispersed WI+ Polymer
1) “History Match and Polymer Injection Optimization in a Mature Field Using the Ensemble Kalman Filter”, EAGE IOR 2013 2) “Chemical EOR project for a Giant NA Field”, OMC 2015
Low Salinity Results
1985 - Peripheral WI
2009 – Bright Water pilot
Q2 2015 – Dispersed WI + Polymer Pilot
Combination of different
Technologies
2016 – Low Salinity Pilot
Q3 2014 – Low Salinity SWCTT
EOR Case Studies
§ Reducing EOR time to market & costs is feasible
§ Take advantage of previous experience
§ Be proactive in seeking for opportunities to improve RF (existing
infrastructures)
§ Still open technical challenges:
§ Going deepwater
§ Carbonates
§ Standard procedures for monitoring phase
§ Keep investing in people and technology even in this low oil price
scenario
§ Promote a more collaborative environment among IOCs, NOCs, SCs
and universities
21
Conclusions Conclusions
Team