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OMV Aktiengesellschaft
Exploration and ProductionProject and country profiles
August 2014
|
DisclaimerThis document does not constitute a recommendation, an offer or invitation, or solicitation of an offer, to subscribe for or purchase any securities and neither this document nor anything contained herein shall form the basis of any contract, investment decisions or commitment whatsoever. This document does not include any financial analysis or financial research and may not be construed to be a or form part of a prospectus. It is being furnished to you solely for your information. This document and its contents are proprietary to OMV Aktiengesellschaft (“the Company”) and neither this document nor any part of it may be reproduced or redistributed to any other person. It may be amended and supplemented.
No reliance may be placed for any purpose whatsoever on the information contained in this document, or any other material discussed verbally, or on its completeness, accuracy or fairness. None of the Company, connected persons, their respective affiliates, or any other person accepts any liability whatsoever for any loss or damage howsoever arising, directly or indirectly, from any use of this document or its contents. The information and opinions contained herein are provided as at the date of this document.
This document is not directed at, or intended for distribution to or use by, any person or entity that is a citizen or resident or located in any locality, state, country or other jurisdiction where such distribution, publication, availability or use would be contrary to law or regulation or which would require any registration or licensing within such jurisdiction. In particular, no recipient of this document or any copy or part hereof shall reproduce, forward, retransmit or otherwise redistribute this document or any copy or part hereof, directly or indirectly, in or into the United States, Canada, Japan or Australia.
This document includes ”forward-looking statements” within the meaning of Section 27A of the U.S. Securities Act of 1933 and section 21E of the U.S. Securities Exchange Act of 1934, as amended. All statements other than statements of historical facts included in this document, including, without limitation, those regarding the Company’s financial position, business strategy, plans, and objectives of management for future operations (including development plans and objectives relating to the Company’s products), are forward-looking statements. Such forward-looking statements involve known and unknown risks, uncertainties and other factors which may cause the actual results, performance or achievements of the Company, or industry results, to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. Such forward-looking statements are based on numerous assumptions regarding the Company’s present and future business strategies and the environment in which the Company will operate in the future and speak only as of the date of this document. None of the future projections, expectations, estimates or prospects in this document should in particular be taken as forecasts or promises nor should they be taken as implying any indication, assurance or guarantee that the assumptions on which such future projections, expectations, estimates or prospects have been prepared or the information and statements contained herein are accurate or complete. As a result of these risks, uncertainties and assumptions, you should in particular not place reliance on these forward-looking statements as a prediction of actual results or otherwise.
This document does not purport to contain all information that may be necessary in respect of the Company or its shares and in any event each person receiving this document needs to make an independent assessment. The Company expressly disclaims any obligation or undertaking to release publicly any updates or revisions to any statements including any forward-looking statements contained herein to reflect any change in the Company’s expectations with regard thereto or any change in events, conditions or circumstances on which any such statement is based.
OMV Group2
||
1 Kurdistan Region of Iraq 2 Discovered technical resources, 3-year average 2013 3 Expected cumulated field life production
More than 1 bn barrels in the project pipeline
4 to 12 years lead time Production
FRDs (Romania)FRDs (Austria)Rosebank (UK)Zidane (Norway)
FRDs (Romania)FRDs (Austria)Habban (Yemen)Schiehallion (UK)Edvard Grieg (Norway)Aasta Hansteen (Norway)Maari Growth (New Zealand)Nawara (Tunisia)
Black Sea NorwayUKFaroe IslandsNew ZealandUnited Arab EmiratesGabonNamibiaMadagascar
Middle East Africa
Domino (Black Sea)FRDs (Austria, Romania)Bina Bawi (KRI 1)Cambo Hub (UK)Zola (Australia)Shuwaihat (UAE)Wisting (Norway)
2016: 70-80 kboe/d
New ventures Exploration Appraisal Development Execution
Production contribution 2021: 180-240 kboe/d
~500mn boe 3
~600 mn boe 3
~270 p.a. 2mn boe
Total volumes
3 OMV Group
||
This page is left blank intentionally
OMV Group4
||
Projects under development
Projects under appraisal
Exploration focus
Countries
Content
OMV Group5
||
Major projects under development
6
Project Country Type Production start 2P reserves Peak
productionProject
investmentsWorking interest Operated
primary year mn boe kboe/d EUR mn %
FRD Romania Oil/Gas 2013-2015 ~100 ~17 100.0 2
FRD Austria Oil/Gas 2013-2015 ~15 ~9 100.0
Maari Growth Oil 2014 ~10 ~7 69.0
Habban Oil 2014 ~28 3 ~10 44.0
Nawara Gas 2016 40-50 ~10 50.0
Schiehallion Oil 2016 ~42 ~12 ~11.8
Edvard Grieg Oil 2016 ~38 ~19 20.0AastaHansteen 4 Gas 2017 ~43 ~18 15.0
Zidane Gas 2018 ~20 ~7 20.0
Rosebank 5 Oil end of decade ~125-150 ~50 50.0
~810
~640
~740
~550
~820 3
~160
~260
~500-550 1
New ventures Exploration Appraisal Development Execution
OP
OP
OP
NO
NO
NO
NO
OP
OP
NO
t.b.d.
1 Cumulated FRDs; forward investments; data as of end-2013 2 Via OMV Petrom 3 Including Phase 1 and 2 of the project 4 incl. Polarled 5 Divestment of ~10-20% stake plannedAll figures net to OMV
under review
OMV Group
||
Field Redevelopment projects, Romania
1 Cumulated FRDs, data as of end-2013 2 investments going forward, data as of end-2013 3 Horizontal Alternating Steam Drive concept
OMV Group7
FRDs: Lebada East, Suplac, Videle G2, Bulbuceni, Burcioaia, Oprisenesti, Independenta Ph. 1, Phoenix Ph.1, Istria Ph. 1, Tazlau Ph. 1 (Pilot), Madulari~100 mn 2P of oil and gas, coming on stream 2013-2015Peak production: ~17 kboe/d 1
Investments: EUR ~500-550 mn 1, 2
Madulari: Upgrade of facilities and redevelopment of the Mamu West area
Suplac: In-situ combustion and cyclic steam injection 3
Plan for additional drilling of 105 wells and modernization of the facilities until 2015
Ensures 10% of the total oil production of Petrom in Romania
Oprisenesti: Water injection and use of HPIS to optimize productionall tanks replaced in water treatment station;
Independenta Ph.1: Identify and develop the underdeveloped areas
Videle G2: Staged Polymer EOR redevelopment 2014 Istria Ph.1: Redevelopment of the producing fields and drilling
exploration wells Tazlau Ph.1: Implementation of five spot water injection in
reservoir by working over existing injection and production
Suplac horizontal wells
ROMANIA
Exploration and ProductionExploration only
||8
Field Redevelopment projects, Austria
1 Cumulated FRDs Note: data as of end-2013, all figures net to OMV
FRDs: 8. TH Phase 1, Erdpress, 16. TH Bockfliess Area,
Nordfeld Gas
~15 mn boe 2P of oil and gas, first oil/gas in 2013-2015
Peak production: ~9 kboe/d 1
Investments: EUR ~260 mn 1
► 8. TH Phase 1: Six new wells on stream
► Erdpress: Four new wells on stream; additional sevenproduction wells and two injectors planned
► 16. TH Bockfliess Area: One new well on stream, twoinjector wells planned
► Nordfeld Gas: Further development of the area by drilling at least one more gas well and building gas infrastructure
► Increase production and recovery by implementing new exploitation strategies
► Upgrade treatment facilities to increase throughput capacity, build new pipelines
AUSTRIA
OMV Group
||9
Maari Growth, New ZealandOMV (Op, 69%), Todd (16%), Horizon Oil (10%), Cue Taranaki
(5%)
Scope: Drill and tie in four horizontal oil producer wells and one
horizontal water injection well
2P reserves: ~10 mn boe
Peak production: ~7 kboe/d
FID May 2013, production start expected in H2/14
Investments: EUR ~160 mn
► Develop the proven oil accumulations through:
► Drilling additional wells and sidetracks
► Optimization of current water flooding
► Review of results of Manaia-2 appraisal well ongoing
► Commenced drilling campaign (10+ months) in April 2014
Ensco 107 drilling rig
All figures net to OMV
OMV Group
||
Habban, Yemen
Central Processing Facility construction site
OMV Group10
OMV (Op, 44%), SINOPEC (37.5%), YOGC (12.5%), YRL(6%),
PSA contract
~28 mn bbl 2P reserves of oil 1, 2
Actual production in 2013: ~6 kboe/d
Peak production (2016): ~10 kboe/d 2
Investment: EUR ~820 mn 2
► Production start via early production facilities in 2006, central processing facility under construction
► 2nd development phase started 2009
► Restart of field development in April 2013 after security upgrade
► Scope: wells, central processing facility and oil export pipeline
► Additional potential in Habban field is under evaluationYEMEN
1 2013 figures 2 Including Phase 1 and 2 of the projectAll figures net to OMV
||
Nawara, Tunisia
11
To be double checked
OMV (Op, 50%), ETAP (50%)
40-50 mn boe of gas coming on stream in 2016
Peak production (2017): ~10 kboe/d
Investments: EUR ~550 mn
► Final Investment Decision taken in 2014
► Gas field development including construction of
gas pipeline and treatment plant
► Gas sales agreement signed
► Line pipe manufacturing completed, ready for delivery to site
► EPCC contractors being mobilized
TUNISIA
Nawara - pipeline yard
OMV Group
All figures net to OMV
||
Schiehallion, UK
OMV Group12
Naming Ceremony Deep Sea Aberdeen, Geoje South Korea
BP (Op, 33.35%), OMV (11.76%), Shell (54.90%)
~42 mn boe 2P of oil and associated gas, coming on stream in
2016
Peak production: ~12 kboe/d
Investments: EUR ~740 mn
► Offshore oil field redevelopment to prolong production to
beyond 2035
► Production ceased in January 2013, old FPSO 1 removed in
Q2/14
► Offshore program including sub-sea infrastructure progressing
according to plan
► New FPSO construction is 83% complete
► Up to 20 further wells planned – five year drilling commitment
for newly built rig 91% complete
UNITED KINGDOM
All figures net to OMV
||
Edvard Grieg, Norway
Platform concept
OMV Group13
All figures net to OMV
Lundin (Op, 50%), OMV (20%), Wintershall (15%), Statoil (15%)
~38 mn boe 2P of light oil and associated gas
On stream in 2016 with peak production of up to 19 kboe/d
Investments: EUR ~640 mn
► Offshore oil field development (~180 km west of Stavanger,
water depth of ~110 m)
► FID taken; project execution according to plan
► Jacket installed offshore by end April 2014
► Topside fabrication ongoing at various Norwegian sites
► Appraisal well Grieg SouthEast confirmed extension of
Edvard Grieg field to South, evaluations ongoing
► Gas export pipelaying commenced in July 2014
► Oil export pipelaying planned for H1/15
NORWAY
||
Aasta Hansteen, Norway
1 Latest start-up date from operator 2 160,000 barrels condensate storage capacity All figures net to OMV
Spar concept
OMV Group14
Statoil (Op, 75%), OMV (15%), Conoco Phillips (10%);
Polarled project (OMV share ~9%)
~43 mn boe 2P of dry gas (from three discoveries), coming on
stream in 2017 1
Production: Up to 18 kboe/d
Investments: EUR ~810 mn
► Deep water development with first floating Spar platform in
Norway and the largest in the world 2
► Overall project progress on plan
► Polarled project: 480 km new gas pipeline and upgrade of
Nyhamna gas processing plant, pipeline coating started
► “Cut of first steel“ for Spar hull in South Korea in April 2014
► Start of production drilling planned for late 2015
NORWAY
||
1 Former Zidane-2 2 Former NSGI: North Sea Gas Infrastructure; Zidane share in Polarled is ~ 2.4%All figures net to OMV
Zidane, Norway
Zidane concept
OMV Group15
RWE Dea Norge (Op, 40%), OMV (20%), Edison (20%), Maersk
(20%)
~20 mn boe expected cumulative production (98% gas)
Start of production: 2018
Peak production: ~7 kboe/d
Investments: t.b.d.
► Development of offshore gas condensate field
► Zidane-West 1 discovery drilled in Q2/12; current evaluations
indicate higher volumes than in 2012 pre-drill
► Concept selection taken in March 2013: Tie-back to Heidrun
platform (15 km); export of gas via Polarled 2 pipeline to
Nyhamna gas processing plant
► FEED completed in Q4/13; optimization initiated
► Project options being reconsidered
NORWAY
|| OMV Group16
Rosebank, UK
1 Intention is to divest between ~10-20% stake 2 OMV viewAll figures net to OMV
FPSO concept
Chevron (Op, 40%), OMV (50% 1), DONG (10%)
125-150 mn boe 2P of oil and associated gas, coming on stream
end of decade
Peak production: ~50 kboe/d
Investment: Under review
► Deep water oil field development including FPSO, production and water injection wells, subsea facilities and a gas export pipeline
► Project in progress; FID planned for 2015 2
► Significant commitments made for newly built drill rig
► FEED optimization progressing well; significant improvements identified
UNITED KINGDOM
17 | OMV Group
Projects under development
Projects under appraisal
Exploration focus
Countries
Content
||
Major projects under appraisal
18
Project Country Type Production start
Cumulative production
Working interest Operated
primary year mn boe %
FRD Romania Oil/Gas 2014-2017 ~200-250 100.0 1
FRD Austria Oil/Gas 2015 ~5 100.0
Cambo Hub 2 Oil/Gas end of decade ~120-150 47.5-65.0
Shuwaihat 3 Gas/NGL end of decade t.b.d. 50.0 4
Domino Gas end of decade 0.75-1.5 tcf 50.0 1
Zola Gas end of decade t.b.d. 20.0
Wisting Oil end of decade t.b.d. 25.0
Bina Bawi Gas t.b.d. t.b.d. 36.0
OP
OP
NO
NO
New ventures Exploration Appraisal Development Execution
OP
1 Via OMV Petrom 2 Cambo, Tornado, Suilven 3 Technical Evaluation Agreement 4 50% of expected gross volumes in appraisal phase to OMV All figures net to OMV
OP
NO
OP
OMV Group
||
Field Redevelopment projects, Romania
1 Data as of end-2013, all figures net to OMV
OMV Group19
FRDs: Videle-Blejesti, Balaria, Tazlau Ph.2, Phoenix Ph.2,
Independenta Ph.2, Istria Ph.2, Bustuchin, Muntenia, Bacea,
Barbuncesti, Calinesti, Preajba Cartojani
~200-250 mn boe expected cumulative oil and associated gas
production 1
Start of production: 2014-2017
Bacea: 3D seismic acquisition in 2014, seismic interpretation,
subsurface studies, workovers and water injection pilot
Barbuncesti: Increase oil recovery factor; 3D seismic
acquisition planned for 2014
Calinesti: New seismic survey to be acquired, early water
injection pilot, further evaluation and subsurface studies, infill
drilling to increase the recovery factor
Preajba Cartojani: Seismic interpretation and subsurface
studies, infill drilling to increase recovery factor
ROMANIA
Exploration and ProductionExploration only
||
Field Redevelopment projects, Austria
Data as of end-2013, all figures net to OMV
OMV Group20
FRD: Matzen field: 8. to 16. TH horizons; Pirawarth & Hochleiten
fields
~5 mn boe expected cumulative oil and gas production
Start of production: 2015
► 8. to 16. TH Matzen
► Increasing production and recovery by drilling additional
wells and upgrading existing wells in all horizons 8. to
16.TH in Matzen
► Continue polymer pilot project
► Successful exploration well in Nordfeld field (Dobermannsdorf
2a) and appraisal well in Matzen field (Prottes Tief Süd 3b)
► Consider change of current IOR strategy (peripheral water
flood only) by implementing pattern water flooding, and
possible introduction of EOR measures (polymer flooding)
AUSTRIA
||
Cambo Hub, UK
OMV Group21
Three projects: Cambo (OMV Op. 47.5%, Chevron 32.5%,
Dong 20%); Tornado (OMV Op. 65%, Dong 20%, Faroe 7.5%,
Idemitsu 7.5%); Suilven (OMV Op. 57.5%, Shell 25%, Statoil
8.75%, JX Nippon 8.75%)
Start of production: end of decade, early production
opportunities being evaluated
Expected cumulative production: 120-150 mn boe oil and gas
► Area hub potential for Cambo, Tornado and Suilven and
exploration potentials
► Cambo – Appraisal program to reduce subsurface uncertainty,
subsurface modelling and development option screening
ongoing, 3D seismic acquisition program started
► Tornado and Suilven – will be progressed with Cambo
► Tie-in possibilities to Cambo for Blackrock exploration wellUNITED
KINGDOM
||
Shuwaihat, U.A.E.
All figures net to OMV
OMV Group22
Wintershall (Op, 50%), OMV (50%)
Gas and condensate (NGL)
Start of production: end of the decade
Appraisal of sour gas and condensate field
Signed TEA with ADNOC in June 2012
OMV: Proven track record of safe development and
production of sour gas (H2S and CO2) in Austria and Pakistan
Drilling program: Three wells in appraisal phase - spud of first
well Shuwaihat 5 on May 18, 2014; drilling ongoing
3D seismic acquisition planned
U.A.E
23 | OMV Group
Domino, Black Sea Romania
Neptundeepblock
BULGARIATURKEY
UKRAINERUSSIA
GEORGIA
500km
ROMANIANeptun
DeepBlock
Ocean Endeavor rig
ExxonMobil (Operator, 50%), OMV Petrom (50%)
Domino-1 discovery: 70.7 meters of net gas pay, preliminary
estimate 1.5-3 tcf (42-84 bcm; 250-500 mn boe), gross
Start of production: towards end of decade 1
► Domino-1: First deep water (~930 m) exploration well offshore
Romania, total depth >3,000 meters below sea level
► Ocean Endeavor rig started drilling the Domino-2 well in July
and is expected to be completed by the end 2014, with results
available in 2015
► 3D seismic data and results from drilling campaign continue to
be processed
► Third exploration well is expected to start following the
completion of Domino-2 drilling
1 If commercially viable
||
Zola, Australia
OMV Group24
Ocean America rig (Bianchi-1)
Apache (Op, 30.25%), OMV (20%), Santos (24.75%), Nippon
(15%), Tap (10%)
Zola-1: Discovery confirmed net gas pay 130 m in 2011
Bianchi-1: Appraisal well in 2013 – net gas pay estimated at
112 m
Start of production: end of decade
► 3D seismic acquisition in 2014/15 to mature further appraisal
targets and assess potential of deeper gas sands found in
Bianchi-1AUSTRALIA
Exploration and ProductionExploration only
||
Wisting discovery
All figures net to OMV
Transocean Barents – Hanssen
OMV Group25
Exploration license PL 537 awarded to OMV 2009
OMV (Op, 25%), Petoro, Idemitsu, Tullow (each 20%) andStatoil (15%)
Estimate 200-500 mn boe (gross) total recoverable oil resources within PL 537 - opened new play type
► Wisting Central discovery in September 2013
► Shallow reservoir approx. 250 m below sea level
► Preliminary estimates 60-160 mn bbl of recoverable oil, 10-40 bn cf of recoverable gas
► Water depth: 400 meters
► Hanssen appraisal well drilled in Q2/14 – proved oil in another structure
► 20-25 meter gross oil column in the main target (StøFormation); Successful formation test
► Preliminary estimates 20-50 mn boe of recoverable resources, largely oil
► Further seismic and appraisal drilling in 2015 to prove up commercial volumes, rig contract awarded
NORWAY
||
Bina Bawi, KRI
Bina Bawi drilling rig
OMV Group26
OMV (Op, 36%), Genel (44%), Government (20%)
Significant gas potential (albeit sour gas)
► Operatorship taken over in August 2010
► Tests of appraisal wells Bina Bawi-4, -5 and -6 completed,
limited oil volumes but significant (sour) gas potential
► Investigating gas commercialization and development
KURDISTAN REGIONOF IRAQ
||
Projects under development
Projects under appraisal
Exploration focus
Countries
Content
OMV Group27
28 | OMV Group
Exploration and productionExploration only
High impact well
Domino-2
Brugdan
Hanssen/Wisting
Affanga Deep
Okala
AtlantisApollo
Lyon
Sula-Stelkur
Neptun DeepPolshkov Lead
Hagar
Berenty Lead
Core countries
North Sea Region
Black Sea
Sub-Saharan Africa
Exploration update and high impact wells 1
1 >25 mn boe net to OMV 2 Exploration/Appraisal 3 Subject to updates based on operational requirements 4 Via OMV Petrom
Well Country Basin/Block Type 2 Spud date 3
Working interest Operated
Affanga Deep Gabon Offshore E Dry 30%
Okala Gabon Offshore E Dry 10%
Apollo Barents Sea E Dry 20%
Hanssen (Wisting) Barents Sea A Oil 25%
Brugdan West of Shetland E Dry 15%
Atlantis NO Barents Sea E Dry 20%
Sula-Stelkur West of Shetland E Drilling 30%
Domino-2 RO Black Sea E Drilling 50% 4
Neptun Deep RO Black Sea E 2014-15 50% 4
Stripfing T1 AT Vienna Basin E 2014-15 100%
Hagar NO Norwegian Sea E 2015 20%
Lyon West of Shetland E 2015 40%
Berenty Lead Berenty E 2015 35%
Polshkov Lead Han Asparuh E 2015 30%
Wisting Appraisal Barents Sea A 2015 25%
NO
OP
NO
NO
NO
OP
NO
NO
NO
OP
OP
NO
NO
NO
NO
New Ventures Montenegro bidding round: Government accepted consortium with MarathonSeismic Namibia: 5,000 km2 3D seismic acquisition finished in JuneDrilling Wisting appraisal well Hanssen proved additional oil Black Sea: Marina-1 exploration success, Domino-2 well spudded in July Luno II: Appraisal drilling ongoing, results expected in H2/14Stripfing T1
29 | OMV Group
Exploration North Sea Region (Norway, United Kingdom, Faroe Islands)
Drilling further four high impact wells 2014-2015 in the region
Norway: Drilling campaign in under-explored Barents Sea
Wisting appraisal well Hanssen confirmed additional oil. Total Wistingpotential within PL 537 in the order of 200-500 mn bbl (gross)
23rd bid round (2015/16): evaluation ongoing
Additional acreage around future Edvard Grieg hub under evaluation (Norwegian North Sea)
United Kingdom/Faroe Islands: West of Shetland
Sula-Stelkur high impact well spudded on June 30, 2014
Further opportunities in maturation phase for 2015/16 including new acreage evaluation
30 | OMV Group
Exploration – Black SeaNeptun Deep (Romania)
OMV Petrom (50%), ExxonMobil (Operator, 50%) Domino-1 discovery in 2012: a play opener;
preliminary resource estimate 1.5 - 3 tcf (42-84 bcm) of gas Drilling campaign 2014/15: Domino-2 well followed by further
deep water exploration drilling, subject to well results and further studies
Midia Deep (Romania) OMV Petrom (42.5%), ExxonMobil (Operator, 42.5%), Gas Plus (15%) 3D seismic processing ongoing
Han Asparuh (Bulgaria) OMV (30%), Total (Operator, 40%), Repsol (30%) 3D seismic acquisition completed (~7,700 km2); continued work program
(G&G studies) will facilitate drilling of two deep water exploration wells in 2015/2016
Operatorship handed over to Total as of April 1, 2014
Skifska exploration block (Ukraine) ExxonMobil and OMV Petrom remain interested in the Skifska license, on
hold due to current circumstances
31 | OMV Group
Exploration Sub-Saharan AfricaMadagascar Offshore Grand Prix license: OMV (40%), Niko Resources Ltd (Operator,
35%), EnerMad (25%) Large, underexplored offshore license with untested deepwater play
fairway Onshore Madagascar: Farmed into two blocks 1, Berenty and Mandabe;
OMV (35%), Tullow (Operator, 65%) 2D seismic acquisition planned for end 2014, 2015 High-impact exploration well in Berenty block scheduled for 2015
Gabon Four offshore licenses operated by Ophir Energy; Ntsina/Mbeli - OMV
(10%); Manga/Gnondo - OMV (30%) Around 8,000 km2 3D seismic acquisition planned in Q3/14 to unlock high
potential deepwater playNamibia Two offshore blocks, OMV (25%), Murphy (Operator) Chasing various plays in close proximity to potential hydrocarbon source
area 5,000 km2 3D seismic acquisition completed in June 2014
1 Subject to approval of the Government of Madagascar
32 | OMV Group
This page is left blank intentionally
33 | OMV Group
Projects under development
Projects under appraisal
Exploration focus
Countries
Content
34 | OMV Group
1 Via OMV Petrom 2 2 months of production in 2013
E&P country footprint Country Type Contract type Production 2013 Operated Key projects/assets
primary kboe/d
Romania 1 Oil/Gas Royalty 171.4 FRDs
Austria Oil/Gas Royalty 34.6 FRDs
Libya Oil/NGL PSA 21.6 Murzuq, Sirte basins
New Zealand Oil/Gas Royalty, JV 16.5 Maari
Tunisia Oil/Gas Royalty, JV 10.2 Nawara
Norway Oil/Gas Petroleum tax regime 4.5 2 Zidane, A.Hansteen, E.Grieg, Gullfaks, Gudrun
UK Oil/Gas Royalty 2.0 Schiehallion, Rosebank, CNS/WoS
Australia Gas Royalty, JV - Zola
Pakistan Gas Royalty 11.0 Latif, Mehar
Kazakhstan Oil Tax/Royalty 11.2 TOC, Komsomolskoe
Yemen Oil PSA 4.8 Habban
KRI Gas PSA, FI - Bina Bawi
UAE Gas/NGL EAA/TEA - East Abu Dhabi, Shuwaihat
Madagascar Oil PSA - Grand Prix Permit, Berenty/Mandabe
Gabon Oil PSC - Mbeli, Ntsina, Gnondo, Manga
Namibia Oil PSA - Blocks 2613A, 2613B
Bulgaria Gas Royalty - Han Asparuh
OP
OP
NO
NO
OP
NOOP
NOOP
NOOP
OP
OP
NO
NOOP
NOOP
NO
NO
NO
NO
35 | OMV Group
Romania – stabilizing productionKey facts:
OMV acquired 51% of Petrom end 2004
Existing blocks/fields: 10 Assets with >230 oil and gas fields
(~45/55% oil/gas mix) and ~10,000 operated wells
Production 2013: 171.4 kboe/d (2012: 170.5 kboe/d)
Contract type/taxation: Royalty
Status / Next steps:
► Improved workover efficiency (~1,600 activities p.a. contributing
~8% of production in 2013)
► “energize OMV”: E.g. +1 kbbl/d from commingled production by
2014; yearly average production achieved in 2013: 1,430 boe/d
out of 1,400 boe/d annual target
► Drill >140 new wells p.a.
► Current recovery factors oil/gas 25%/49%
Production decline successfully stopped kboe/d
190
200
160
10
180
0
170171
2012
171
2011
174
20102009
181174
20132008
189
2007
193
36 | OMV Group
Austria – maintain production level Key facts:
OMV operations since 1956
Oil and gas fields: 4 assets with ~40/60% oil/gas production mix
Contract type/taxation: Royalty
Production: 34.6 kboe/d in 2013 (2012: 38.0 kboe/d)
Status / Next steps:
► FRDs (Erdpress, 8. TH Phase 1, 16. TH Bockfliess Area,
Nordfeld Gas)
► Drill approximately 15 to 20 new wells per year – development,
injection and exploration and appraisal wells
► Polymer injection pilot – traces of polymer produced
► Successful technology pilots to be rolled out to other countries0
10
20
30
40
50
201320001990
Steadily keeping production frommature basin at a high levelkboe/d
37 | OMV Group
Libya – situation remains volatileKey facts:
OMV presence since 1975, production since 1985
Existing blocks/fields: Murzuq and Sirte Basins
Oil and NGL
Contract type/taxation: PSA
Production: 21.6 kboe/d in 2013 (2012: 29.5 kboe/d)
Status:
► Political situation remains volatile
► Production shut-ins throughout the year
► Sirte production shut in since closure of ports in the east
in July 2013. Zueitina terminal re-opened in May 2014
► Conducted equity lifting from Zueitina in May
► Currently drilling the 6th exploration well since business
resumption in 2011
ADWOC 38 Rig, NC115, Libya
MurzuqBasin
SirteBasin
38 | OMV Group
New Zealand – offshore production and exploration opportunities
Key facts:OMV holds interests in 10 licenses: 3 production and 7 exploration
permits; 4 as operator
Contract type/taxation: Royalty, JV
Producing asset base: Maari oil field (operated), Maui and
Pohokura gas fields (non-operated, JV)
Production: 16.5 kboe/d in 2013 (2012: 19.4 kboe/d)
Status / Next steps:► KanTan IV semi-submersible drilling rig arrived August 2013:
► Manaia-2 appraisal well drilled (encountered hydrocarbons)► Whio-1 exploration well drilling started in July► Two further exploration wells in non-operated Maui license in
H2/14► Ensco 107 jack-up drilling rig commenced operations in April
2014, production start expected H2/14► Great South Basin: 3D-seismic data evaluated, JV entered into
next exploration phase including well commitment for 2016
FPSO RAROA and well head platform
||
Tunisia – developing gas fields in the South Key facts
Concessions and Permits: Cherouq, Durra, Anaguid, Nawara,
Sidi Mansour (all operated) and non-operated assets 1
Contract type/taxation: Royalty, JV
Production: 10.2 kboe/d in 2013 (2012: 11.2 kboe/d)
Nawara:
► FEED completed; Plan of development signed
► FID taken in March 2014
► Gas Sales Agreement signed
► EPCC contractors being mobilized
► Production start: 2016
Other:
► Ashtart revamp project completed
1 Ashtart (JV), Guebiba, Cercina, Adam
39 OMV Group
40 | OMV Group
Norway – developing the portfolio
1 Includes 480 km gas pipeline from Aasta Hansteen to Nyhamna and upgrade of Nyhamna gas processing plant
Key facts: Active in 36 licenses, thereof 9 operated 2 new licences awarded in January 2014Contract type/taxation: 78% Petroleum tax regime
Status / Next steps: Gudrun production started in April 2014 – slow ramp-up till year
end; Gullfaks Q1/14 production 27.5 kboe/d Edvard Grieg (20%): First production expected in 2016;
operator Lundin; execution ongoing as planned Luno II discovery (20%) aquired – drilling of Luno II Central
appraisal well ongoing Aasta Hansteen (15%): First production expected in 2017; first
Spar for Norway in Korea; stake of ~9% 1 in the Polarledproject
Zidane (20%): Project options being reconsidered Wisting discovery: Further appraisal drilling and seismic
evaluations ongoing
Gudrun
41 | OMV Group
UK – focus on West of Shetland area
FPSO Schiehallion
Existing production: Jade (5.57%)
Operated by OMV:
Cambo (47.5%), Tornado (65%), Suilven (57.5%)
Not operated by OMV:
Rosebank (50%); Schiehallion/Q204 (11.76%); Jackdaw (9.7%)
Key prospects: Sula/Stelkur, Blackrock, Lyon, Spitfire
Contract type/taxation: Royalty
Status / Next steps:
► Schiehallion Redevelopment: On schedule for first oil 2016
► Rosebank: Project progressing, FID planned for 2015, first oil
end of decade
► Cambo/Tornado/Suilven: Investigating potential for hub
development
► Jackdaw project in appraisal stage; maturing options; expected
to move to development stage after completion of options
screening
42 | OMV Group
AustraliaKey Facts:
OMV holds 6 exploration licenses, 1 as operator
Contract type/taxation: Royalty, JV
WA-49-R Zola Discovery:
2011 gas discovery (Zola-1) on Australia’s Northwest Shelf
(OMV 20%)
► Bianchi appraisal well drilled April to July 2013; Multiple gas-
bearing sand intersected, net gas pay estimated at 112 m
► 3D seismic acquisition in 2014/15 to mature further appraisal
targets and assess potential of deeper gas sands found in
Bianchi-1
WA-320-P Palmerston-1 exploration well (Apache operated)
► Well committed for 2014 to be deferred depending on 3D
seismic acquisition results
Stena Clyde rig (Zola-1)
43 | OMV Group
PakistanKey Facts:
First gas discovery in 1993, Miano field
OMV active in 8 exploration blocks
Six producing assets: Sawan, Miano, Latif, Tajjal, Mehar, Mubarak
Production: 11.0 kboe/d in 2013 (12.8 kboe/d in 2012)
Latif: Petroleum Policy 2012: received the Latif Gas Provisional
Price Notification on dual pricing from OGRA
Status / Next steps:
► Mehar Phase 1: Gas condensate processing facility completed
and commissioned, production started in Q4/13
► Inauguration of the Mehar gas plant by the Prime
Minister on June 16, 2014
► Mehar Phase 2: Drill additional production wells, double
gas/condensate processing facilities and build condensate
export pipeline; completion of project planned for Q4/16
Pakistan, Mehar Pipeline
44 | OMV Group
KazakhstanKey facts:
Asset base: Komsomolskoe oil field and Tasbulat Oil Company
fields - TOC (Tasbulat, Turkmenoi and Aktas)
Contract type: License - Tax/Royalty
Production: 11.2 kboe/d in 2013
Status / Next steps:
TOC and Komsomolskoe:
► Further pursue water injections schemes in order to secure
reservoir pressure support and slow down the production
natural decline
Production in kboe/d
12.212.0
9.9
6.35.74.65.0
2.5
0.0
12.5
10.0
7.5
201220112010200920082007 2013
11.2
45 | OMV Group
YemenKey facts:
Existing blocks/fields: 6 blocks, in 4 operator1 block under production/development (S2), rest exploration
Contract type/taxation: PSA
Production: 4.8 kboe/d in 2013
Status / Next steps:
Challenging security situation and extended road blockages affecting mainly transportation; several attacks on the pipeline
Habban Phase-2 development project ongoing (workover/drilling and CPF construction operations)
Preparing for start of construction of oil export pipeline, 3D seismic acquisition and maturation of additional drilling prospects
Early production of existing wells by EPFs is self-financing Habban field development
Habban development in block S2
46 | OMV Group
Kurdistan Region of Iraq, KRIKey facts:
OMV is operator in Bina Bawi (PSA) and holds 10% financial
interest in Pearl Petroleum Ltd. (Khor Mor and Chemchemal gas
condensate fields)
Pearl production: 68 kboe/d (gross)
Bina Bawi:
► OMV (Op, 36%), Genel (44%), Government (20%)
► Tests of appraisal wells Bina Bawi-4, -5 & -6 completed
► Only limited oil volumes but significant gas potential (albeit
sour)
► Investigation of gas commercialization / marketing activities
ongoing
Bina Bawi-3 discovery
||
United Arab Emirates, U.A.E.
All figures net to OMV
Shuwaihat: Wintershall (Op, 50%), OMV (50%)
Signed TEA with ADNOC in June 2012
Sour gas and condensate field – appraisal phase
Appraisal program: 3 wells - spud of first well, Shuwaihat 5, on
May 18, 2014; drilling ongoing
Start of production: end of decade
East Abu Dhabi: OMV(Op, 60%), ADNOC (40%)
► OMV signed exploration agreement with ADNOC for East Abu
Dhabi on June 24, 2013
► Acquisition of 3D seismic started end of June 2014
► First exploration well planned for 2015/16
OMV Group47
EAA area
|
Bulgaria OffshoreKey facts:
OMV (30%), Total (Op, 40%), Repsol (30%)
Operatorship handed over to Total as of April 1, 2014
Status / Next steps:
► 3D seismic acquisition completed (~7,700 km2); 2D seismic acquisition completed (3,000 km); processing and interpretation being performed by OMV
► OMV to perform sea-bottom survey and seabed sampling activities in 2014
► Continued work program (G&G studies) will enable drilling of two deep water exploration wells in 2015/2016
► Drill first high impact exploration well in 2015 and second high impact exploration well in 2016
48 OMV Group
49 | OMV Group
MadagascarKey facts:
Grand Prix permit (offshore): OMV (40%), Niko Resources (Op,
35%), EnerMad (25%)
Contract type/taxation: PSA
OMV will take over operatorship in 2014
3D seismic survey planned for 2015 (~4,500 km²) 1
Water depth up to 1,700 m
Berenty/Mandabe permits (onshore): OMV (35%), Tullow (Op, 65%)
►Contract type/taxation: PSA
► Farm-out agreement with Tullow signed end March 2014, awaiting
government approval
► Planned activities: 2D seismic in Mandabe (2014), exploration well
in Berenty (2015)
1 Subject to partners approval
Grand Prix Permit
BerentyPermit
MandabePermit
50 | OMV Group
GabonKey facts:
Manga/Gnondo: Ophir (Op,70%), OMV (30%)
Mbeli/Ntsina: Ophir (Op, 40%), Petrobras (50%), OMV (10%)
Contract type/taxation: PSC
Status / Next steps:
Government approval received for Ophir transaction in June 2014, closed with Ophir July 16, 2014
► 3D seismic program covering approx. 8,500 km2 over the undrilled parts of the blocks planned to commence in Q3/14, and to last up to 6 months
Manga Marin / Gnondo Marin blocks:Total block size: ~6,000 km2
Water depth: 100-2,500 m
Mbeli Marin / Ntsina Marin blocks:Total block size: ~6,500 km2
Water depth: 135-2,300 m
Affanga Deep
Pre-Salt
Post-Salt
LEADS
Mbeli
Ntsina
Gnondo
Manga
Gabon
Port Gentil
51 | OMV Group
NamibiaKey facts: OMV (25%), Murphy (Op, 40%), Cowan (20%),
NAMCOR (15%)
Contract type: Production Sharing Agreement
Status / Next steps:
► Deal for OMV and Murphy to farm-in to Cowan license
closed in April 2014
► 5,000 km2 3D seismic campaign conducted between April
and June, within time and under budget
► One year license extension granted to allow drill or drop
decision to be made by end 2016Blocks 2613A and 2613B offshore blocks:Size of the permit: 11,000 km2
52 | OMV Group
Abbreviations
CNS Central North Sea
CPF Central Processing Facilities
EAA Exploration Activity Agreement
EPCC Engineering, Procurement, Construction
and Commissioning
EPF Early Production Facility
FEED Front End Engineering and Design
FI Financial Interest
FID Final Investment Decision
FPSO Floating Production, Storage and
Offloading Vessel
FRD Field Redevelopment
G&G Geology and Geophysics
HPIS High Pressure Injection Stations
JV Joint Venture
KRI Kurdistan Region of Iraq
NAMCOR National Petroleum Corporation of Namibia
NSGI North Sea Gas Infrastructure
OGRA Oil & Gas Regulatory Authority
PDO Plan for Development and Operation
PSA Production Sharing Agreement
PSC Production Sharing Contract
TEA Technical Evaluation Agreement
WoS West of Shetland
53 | OMV Group