PETROLEUM EXPLORATION IN PORTUGAL Direcção Geral de Energia e Geologia Divisão para a Pesquisa e Exploração de Petróleo PETROLEUM EXPLORATION IN PORTUGAL

Summary Global Overview Exploration Activity Petroleum Systems

Global Overview DGEG – DPEP The Portuguese Meso-Cenozoic basins DPEP is the Division, within DGEG, responsible for all matters regarding petroleum exploration and production in Portugal. http://www.dgge.pt/dpep/intro_en.htm The Portuguese Meso-Cenozoic basins From N to S: Porto basin: ca. 4.000 km2 Galicia basin*: over 6.000 km2 Lusitanian basin: ca. 26.000 km2 Peniche basin: over 22.000 km2 Alentejo basin: over 13.000 km2 Sagres basin: over 20.000 km2 Algarve basin: ca. 12.000 km2 Cadiz basin*: over 10.000 km2 * within Portuguese waters

Exploration Activity Currently Operating Companies Operators of Previous Concessions: Currently Operating Companies CPP Sceptre Marinex Shell Salén Sun Pecten Taurus Esso Neste Mohave Challenger C. Dodge Chevron Union Texas Texaco Eurafrep Petrogal MOHAVE OIL & GAS 5 concessions in the Onshore and Shallow Offshore of the Lusitanian basin PETROBRAS/GALP/PARTEX 4 concessions in the Deep Offshore of the Peniche basin PETROBRAS/GALP * 3 concessions in the Deep Offshore of the Alentejo basin REPSOL/RWE 2 adjudicated areas in the Deep Offshore of the Algarve basin * Previously held by HARDMAN/GALP/PARTEX

The Portuguese basins are still underexplored Exploration Activity Wells Drilled Seismic Acquisition 72,600 km of 2D seismic acquired from 1955 to 2008: Onshore: 5,855 km Shallow Offshore: 31,823 km Deep Offshore: 34,922 3D seismic acquisition in 2010 - 2011: Onshore: 247 km2 Shallow Offshore: 1000 km2 Deep Offshore: 3096 km2 67 exploration wells out of a total of 147 drilled wells: Porto basin: 5 wells Lusitanian basin: 58 wells Algarve basin: 4 wells The Portuguese basins are still underexplored

Wells with most significant Shows

PETROLEUM SYSTEMS

Source Rocks Mesozoic Source Rocks Paleozoic Source Rocks Kimmeridgian: shales in the lower part of this formation represent source rock in some wells; richest in organic matter is the Cabrito Member Oxfordian: limestones with fair to good petroleum potential (2 to 4 kg HC/ton rock), thicknesses ranging from 20 to 110 m and fair TOC content (up to 3%) Mesozoic Source Rocks Middle to Lower Jurassic: carbonate shales with TOC fair to rich (2.5 to 10%), initial petroleum potential fair to very rich (10 to 45 kg HC/ton rock), high thickness (140 to 190 m) and maturity ranging from 0.7% to 2% Ro eq Sinemurian: shale beds with fair to good petroleum potential (1.1 to 60 kg HC/ton rock), small thickness (5 to 25 m), maturity from 0.7% to 2% Ro eq. and poor to good TOC (up to 3.6%) Sinemurian: shale beds with fair to good petroleum potential (1.1 to 60 kg HC/ton rock), small thickness (5 to 25 m), maturity from 0.7% to 2% Ro eq. and poor to good TOC (up to 3,6%) Hettangian: dark grey to black shales with fair to good TOC (up to 3.2%), locally fair to good S2 (19 kg HC/ton rock). Net thicknesses variable from 0 to 120 m Paleozoic Source Rocks Marine Carboniferous shales with Ro eq. 3.5% Visean age shales with Ro eq. 1.7% Silurian black shales with Ro eq. between 1.75% and 3.5%

Reservoirs Lower Cretaceous: loosely consolidated sandstones to unconsolidated sands represent one of the best potential reservoirs. Its continuous thickness and geographic distribution also enhances this unit as a good reservoir Kimmeridgian: good sandstone reservoirs have been reported in the Torres Vedras, Arruda dos Vinhos & Barreiro areas Upper Oxfordian: reefal, vugular and fractured reservoirs exist and oil filled fractures are common Middle Jurassic: subaerial exposure and karstification may have enhanced significantly reservoir quality. Reefal and high-energy facies may have reservoir quality Sinemurian: limestones and dolomitic limestones with porosities of less than 5%, but vacuolar and fractured sections exist within the formation Triassic: porosity is variable, in general up to 20%. It may be considered good reservoir rock for the paleozoic potential source-rocks

Seals Tertiary: marls and clays mainly developed in deep offshore basins Cenomanian: argillaceous limestones Jurassic: argillaceous limestones, marls and clays with variable thicknesses, interbedded within carbonates and terrestrial sediments Hettangian: Evaporites (mainly salt) and marls

Traps Structural trap Stratigraphic Trap Late Inversion Tertiary / Cret reservoirs Late Inversion structure Tertiary / Cret reservoirs Stratigraphic Trap Miocene channel fill (Mauritania analogue) Miocene turbidites Miocene turbidite basin floor fan

Basin Analogs Canada and Iberia Atlantic conjugated margins Cadiz and Algarve basins This proven Tortonian-Messinian sedimentary model has been extrapolated into the Algarve basin in Portuguese waters Poseidón fields, offshore Spanish Gulf of Cádiz, produced biogenic gas from Messinian turbidite sands. Tertiary channel analogs Basin locations prior to main Atlantic rifting phase Mauritania and Iberia Atlantic margins Similar Geologic settings until break-up in early Cretaceous Portugal Mauritania

PETROLEUM EXPLORATION IN PORTUGAL Thank You 谢谢 Divisão para a Pesquisa e Exploração de Petróleo