SPECIAL TOPIC: PETROLEUM GEOLOGY

Offshore Argentina: Lessons from previous exploration

Jonathan Castell1*, Andrew Lavender1 and James Scotchman1 provide new insight into basin evolution, play types, and hydrocarbon prospectivity.

Introduction of the South Atlantic. Of these, only two (Austral and San Jorge) Argentina’s Energy and Mining Ministry is in advanced prepara- have been extensively explored, and five (Salado, Colorado, tions to stage a new offshore licensing round in 2018 — the first Rawson, San Julian, and Malvinas) have been drilled with lim- in almost a decade. Despite its size (approximately 1.5 million ited success. The final basin — the Argentina Basin (sometimes km2, equivalent in scale to the US Gulf of Mexico) and its referred to as the East Patagonia Basin) — is the only deepwater moderate water depths, there have only been approximately basin and remains undrilled. 150 exploration wells drilled to date, making it one of the least Exploration frontiers with proven petroleum systems and explored Atlantic provinces. strong analogues such as the Argentine offshore are rare, driving The Argentine margin is underlain by a series of eight strong industry interest in the area. This is further stimulated by diachronously rifted basins (Figure 1) associated with the opening recent success around the Atlantic margins to the north in Brazil and Guyana, in West Africa, and in the UK-administered North Falkland Basin. Despite being an underexplored province, there is a vari- ety of publicly available legacy data for the Argentine margin (Figure 1). Available data for offshore Argentina include gravity and magnetics, seismic, well data, rock property information, and geochemistry data — all of which can be augmented by additional datasets from local and Atlantic margin analogues. As demonstrated in this article, these data, when interpreted in the context of a robust sequence stratigraphic and geodynamic framework, can provide new insight into basin evolution, play types, and hydrocarbon prospectivity.

Exploration context Hydrocarbon exploration offshore Argentina began in 1969, focusing initially in the Salado, Colorado, and San Jorge basins. Approximately 30 wells were drilled by 1971, although results were disappointing and despite some shows, no commercial discoveries were made (Figure 2). A second phase of explora- tion began in the early 1980s when a consortium led by Exxon drilled a series of wells testing offshore extensions of plays from the onshore Austral Basin. The discovery of multiple large gas fields (Aries, Vega Pléyade, Carina) during this campaign provided renewed optimism for the province. Exploration continued at a steady rate until the late-1990s when a plateau in the discovery rate, compounded by acute economic instability, resulted in a cessation of drilling activity. Only a few wells have been drilled and only two relatively minor discoveries have been made since the turn of the century. The first

Figure 1 Location map of the major sedimentary basins of the Argentine margin and only deepwater well (Malvinas x-1) was spudded in 2011 overlain by the distribution of public domain seismic and exploration well data in the Malvinas Basin in water depths just greater than 500 m. available for this study. Wells mentioned in the text are labelled. Unfortunately, it failed to prove a petroleum system in the area.

1 Halliburton Landmark * Corresponding author, E-mail: [email protected]

FIRST BREAK I VOLUME 36 I MARCH 2018 47 SPECIAL TOPIC: PETROLEUM GEOLOGY

Figure 2 Cumulative offshore-discovered hydrocarbon volume (red) and wells drilled by year (black line) illustrating the recently static state of exploration in offshore Argentina. (Figueroa, 2010; Rystad Energy, 2017).

Pre-rift Documented pre-rift stratigraphy is Permian in age and is present in the north of the study area. The supercontinent of Gondwana dominated global plate configuration during the Permian, and the Argentine margin was influenced by a series of collisions result- ing in the formation of the Hesperides Basin that represented a foredeep for the Gonwanides orogeny. The pre-rift stratigraphy here consists of organic-rich shales deposited during sea-level highstands and deep-marine sands shed from the Gonwanide mountains to the south. The southern part of the study area was uplifted as part of the Gonwanides orogenic belt (Pangaro et al., 2016), resulting in no age-equivalent pre-rift stratigraphy being deposited and/or preserved.

Syn-rift The disaggregation of Gondwana began in the latest Triassic and was the precursor to the opening of the South Atlantic. Continental extension during the Late Triassic–Middle Jurassic is believed to have initiated and reactivated basin formation

Figure 3 Paleo Digital Elevation Model (PaleoDEM) showing the global plate across the Argentine continental shelf, resulting in the earliest configuration during in the Early Cretaceous period and the opening of the South syn-rift deposits being represented by volcanics, volcaniclastics, Atlantic. and continental sandstones (Loegering et al., 2013). In the Late Jurassic period a renewed phase of rifting began, leading to the However, between 1998 and 2017 three drilling campaigns were opening of the South Atlantic. Initial rifting began in the south of undertaken in the UK-administered North and South Falkland the study area and progressed northward, reaching the north of Basins, resulting in multiple discoveries of both oil and gas and the study area by the Early Cretaceous period (Figure 3). During igniting a keen interest in the province in general. this time, continental and lacustrine sediments were deposited The upcoming offshore licensing round, announced by Argen- in graben and half-graben structures. Seafloor spreading in the tina’s Energy and Mining Ministry, will occur in three annual Early Cretaceous period was accompanied by transient volcanic rounds and is expected to begin with the Austral, Malvinas, and activity, resulting in the emplacement of extensive seaward Argentina Basins. 2D multi-client seismic data is currently being dipping reflectors that are readily identifiable in seismic profiles acquired and processed across these fundamental areas. (Hinz et al., 1999; Franke et al., 2007).

Tectonostratigraphic evolution Post-rift The geological history of the margin is dominated by the opening The initial stage of post-rift subsidence resulted in marine of the South Atlantic from the Middle-to-Late Jurassic until the transgressions across the basins ranging in age from Berriasian mid-Cretaceous. As most of the basins along this margin devel- in the south to Barremian in the north of the study area. Many oped during this Gondwanan break-up phase, they exhibit similar of these initial marine deposits are organic-rich. A period of (though sometimes diachronous) depositional patterns and related tectonic quiescence and thermal subsidence from the Aptian petroleum systems elements. period resulted in widespread marine transgressions during the

48 FIRST BREAK I VOLUME 36 I MARCH 2018 SPECIAL TOPIC: PETROLEUM GEOLOGY

mid-Late Cretaceous and Tertiary (Autin et al., 2013; Loegering Farther north, in the Colorado Basin, strong continuous reflec- et al., 2013). tors identified on seismic profiles might represent organic-rich lacustrine facies (Bushnell et al., 2000). Additionally, Fryklund Petroleum system elements et al. (1996) described a mature source rock of syn-rift origin Throughout the geological history of the Argentine offshore penetrated by the Cruz del Sur x-1 well. Average TOC content is margin, multiple periods of source rock, reservoir, and seal dep- reported to be 2.4% with a hydrogen index (HI) of 500. osition have occurred. Figure 4 summarizes this information in Because of the strong stratigraphic similarities of the syn-rift a regional petroleum systems events chart. Knowledge from the basins, it is expected that continental and lacustrine, organic-rich individual basins was collated to build a regional understanding deposits might be relatively widespread within basin depocentres. of petroleum system element occurrence. Similarities can be This is important for prospectivity of the Rawson and San Julian observed among the basins, indicating that regional events are a basins where a younger Aptian source rock is predicted to be absent. controlling factor in the distribution of source rocks, reservoirs, and seals across the area. Early Sag (Aptian) Aptian source rocks are the primary contributor for discoveries in Source rocks the Austral Basin (Rodriguez and Cagnolatti, 2008) and are likely Pre-rift (Permian) to be important along the margin. Deposition of organic-rich The oldest possible source rocks occur in the north of the study mudstone was widespread and is contemporaneous with a global area where Permian kerogen-rich shales have been penetrated in Ocean Anoxic Event (OAE1a) (Naafs et al., 2016). Marine organ- the Cruz del Sur x-1 and Puelche x-1 wells in the Colorado Basin ic enrichment is identified in multiple DSDP wells in the South (Fryklund et al., 1996). These organic-rich strata in the Puelche Atlantic (Tissot et al., 1980) and described in the Bredasdorp and x-1 well have been correlated to the Whitehill, Prince Albert, and Pletmos basins in South Africa (Van Der Spuy, 2003), illustrating Collingham formations (known organic-rich units on the African its widespread occurrence. margin) with an inferred Cisuralian age. Remnant deposits of the In the Austral and Malvinas basins, the Lower Inoceramus Permian age are likely to be laterally discontinuous, and while Formation was deposited during a second-order transgression of a contribution from this interval should not be ignored, it is not the Dungeness Arch. Progressive onlap and organic enrichment thought to form the primary charge for petroleum systems. occurred from the Barremian and peaked during the Aptian period (Galeazzi et al., 1998; Rodriguez and Cagnolatti, 2008; Legarreta Syn-rift (late Jurassic to Early Cretaceous period) and Villar, 2011). A series of graben and half-graben structures formed during Source rocks of this age have not been penetrated in the the early rifting phase of the South Atlantic, providing an ideal north of the study area, although they are predicted to occur environment for restriction, water column stratification, and the in the Colorado, Salado, and Argentina basins. In the Colorado preservation of organic matter. Organic-rich horizons in this interval Basin, strong, laterally continuous seismic reflectors are inter- are highly variable in thickness and extent. The oldest syn-rift preted to represent the Aptian organic-rich interval, although source rocks are found in the Malvinas and Austral basins where the with high levels of uncertainty (Bushnell et al., 2000). Similar Tobifera Formation (Serie Tobifera) contains up to 3% total organic characteristics are observed on seismic data in the Argentina carbon (TOC) and has been speculated to act as a contributor to Basin (Figure 5) where the presence of the Aptian source rock some shows and discoveries in the area (Legarreta and Villar, 2011). is vital for prospectivity.

Figure 4 Petroleum systems events chart detailing the temporal and geographic distribution of proven and potential petroleum systems elements across the Argentine offshore, highlighting the main time intervals wherein coeval, source, reservoir, or seal facies are deposited regionally.

FIRST BREAK I VOLUME 36 I MARCH 2018 49 SPECIAL TOPIC: PETROLEUM GEOLOGY

Figure 5 Seismic section through the Argentina Basin displaying the predicted presence of source and reservoir facies. Source rock facies were identified based on the presence of high amplitude, laterally continuous reflectors were observed to onlap the margin. Reservoir facies have been modelled based on the interpretation of several back-stepping Cretaceous delta systems and the predicted downslope transport related to these. Higher amplitude reflectors can be seen to pinch-out, suggesting the presence of potential reservoir targets. Seismic data was obtained from Triezenberg et al. (2016).

Marine transgression did not reach all basins during the Significant volumes of volcanics and associated lithic fragments, Aptian period. In the San Jorge Basin, a lacustrine environment extruded during rift basin formation, are likely to have impacted remained, and black shales of the Pozo D-129 Formation were reservoir potential in many parts of the syn-rift stratigraphy. An deposited. This is the principal source rock horizon in the basin illustration of this can be seen in Figure 6, showing the decreased and charges all discoveries. TOC content of 3% and HI of 200 to permeability observed in syn-rift sandstones in the Austral Basin. 500 are typical (Sylwan, 2001). In general, across the study area, the quality and lateral continuity of sands in this interval are highly variable. Reservoirs Potential reservoir facies occur at multiple levels in the regional Early Cretaceous transgressive sandstones stratigraphy (Figure 4). During this evaluation, the focus was the Cretaceous transgressive sandstones are the most important res- most regionally extensive and prospective stratigraphic intervals, ervoirs in the region in terms of hydrocarbons discovered to date. which are described in this section. Other reservoirs, such as Permian The presence of these sandstones is interpreted to be restricted to turbidites, Middle-to-Late Cretaceous shallow marine and lacustrine basin depocentres where sufficient accommodation space existed. sandstones, Cenozoic turbidites, and Eocene carbonate build-ups, are In the Austral and Malvinas basins, transgressive sandstones also identified in the region and are worthy of further consideration. of the upper Springhill Formation progressively onlap the Dungeness arch from the south, east, and west. While the Late Jurassic to Early Cretaceous syn-rift sandstones back-stepping wedge advanced landward, fluvial systems were Continental and lacustrine sandstones deposited on graben flanks replaced by shallow marine systems with excellent reservoir are predicted in all basins along the margin and constitute a qualities. Porosities of 8 to 32% and permeabilities of 2300 mD possible reservoir target. In the Austral and Malvinas basins, are recorded (Galeazzi, 1998). the Tobifera and lower Springhill formations are reservoirs for In the Colorado Basin, the Early-to-Middle Cretaceous is multiple discoveries, although they are often compartmentalized. represented by the Fortin Formation, a series of coarse sandstones Reservoir quality in the continental part of the Springhill Forma- deposited across the basin. Reports suggest that these sandstones tion is encouraging, with porosities of up to 24% and net-to-gross (along with the overlying Colorado Formation sandstones) are of up to 100% (Schwartz et al., 2011). mineralogically and texturally immature, although good porosi- Encouraging reservoir characteristics were identified in the ties of up to 32% have been recorded with thicknesses between Colorado Basin where the Cruz del Sur x-1 well was drilled on 700 to 1100 m (Bushnell et al., 2000). the basin flank and intersected 280 m of syn-rift sandstones with porosities of 15 to 20% (Bushnell et al., 2000). In the Rawson Late Cretaceous lowstand sandstones Basin, red-beds were encountered in the Tayra-1 well that had Possibly the most exciting play in the entire Atlantic province is disappointing reservoir properties (Otis and Schneiderman, 2000). that of Late Cretaceous turbidites deposited in deepwater areas.

50 FIRST BREAK I VOLUME 36 I MARCH 2018 SPECIAL TOPIC: PETROLEUM GEOLOGY

Proven analogues in Guyana (e.g., Liza), Brazil (e.g., Albacora), tool. A multi-disciplinary dataset was used to create Gross Dep- and the African transform margin (e.g., Jubilee) might have ositional Environment (GDE) maps for source rock, reservoir, application to offshore Argentina. and seal intervals. Seismic megasequence interpretations were A thin Late-Cretaceous deepwater sandstone belonging to incorporated to generate a series of depth maps (Figure 7), the Arenas Glauconiticas Formation containing oil shows was illustrating the evolution of basin fill over time. Understanding intersected in the Salmon x-1 well in the Malvinas Basin the regional geological evolution, including local and conjugate (Galeazzi, 1998) and constitutes the only recorded intersection of margin analogues, is of particular importance because of the this play type in the study area. Multiple unconformities on the relatively sparse data available in the study area. shelf during the Late Cretaceous period, evident in seismic and GDE maps were used as a principal input to assess the chance well data (Figure 5), indicate reworking of sandy sediments into of each petroleum system element being present. Rock properties, deeper water areas. Channels, turbidite lobes, and possible sandy source rock maturity, and temperature data were evaluated in contourites are identified on seismic data in the Argentina Basin, the context of regional depth surfaces to evaluate the likely providing more evidence of a reservoir target. effectiveness of reservoirs and the extent of hydrocarbon charge. The combination of these elements provides a composite chance Seal map, identifying the most prospective play fairways. Regional seals were deposited during two periods of marine Three plays were evaluated based on the principal regional transgression. As well as being an effective source, the Lower reservoir horizons, although additional, more spatially restricted Inoceramus and regional Aptian OAE1a organic-rich shale reservoirs could be incorporated into a similar analysis. have been modelled to act as a seal along the Argentine margin. Proven sealing capabilities of the Lower Inoceramus Shale are Play-by-play results summary observed in the Campo Indio Field in the Austral Basin. A marine Late-Jurassic-to-Early-Cretaceous syn-rift clastic play transgression during the Maastrichtian-to-Early Paleocene period This play is proven in the onshore portion of the San Jorge Basin, deposited mudstones of the Pedro Luro Formation across most although reservoirs are generally discontinuous and of varying of the study area, providing an effective and widespread seal. Additionally, local seals exist at multiple intervals throughout the Cretaceous period.

Regional prospectivity screening process A prospectivity screening workflow, (Figure 8) has been applied on a regional scale to build a deeper understanding of the identi- fied play intervals. To facilitate the best understanding, sequence stratigraphic analysis was used as a correlative and predictive

Figure 6 Porosity permeability for the reservoir intervals discussed. The older reservoirs display much lower permeabilities, which are likely because of a volcaniclastic composition. Permeabilities are greater in the younger reservoirs. Figure 7 Depth frameworks constructed from seismic and well data for input into Note the high quality of the Early Cretaceous sandstones. Data derived from various the basin screening workflow. Maps represent A) Economic Basement, B) Base sources and collated in the Exploration Insights database. Cretaceous, C) Aptian, D) Maastrichtian.

FIRST BREAK I VOLUME 36 I MARCH 2018 51 SPECIAL TOPIC: PETROLEUM GEOLOGY

quality. Elsewhere, the play has a limited extent, restricted to Malvinas Basin where depths of burial and tectonic complexity rift basin margins and relying on laterally discontinuous syn-rift increase. source rocks or a charge from underlying Permian stratigraphy. • The San Julian and Rawson basins have each been tested by a Reservoirs are influenced by the coeval deposition of volcanics single well. Based on our analysis, both basins are likely to be and as a consequence are of generally poor quality and are unlike- high-risk provinces because of the perceived lack of charge. ly to be effective at depth across much of the region. However, • The Colorado and Salado basins have been explored to a limited well data does provide some encouragement e.g., the Cruz moderate extent, though with limited success. It is anticipated del Sur x-1 well in the Colorado Basin. that multiple play intervals might be effective, particularly on the margins of the basins. Early Cretaceous transgressive sand play • The San Jorge Basin is different in nature from the other basins. This is the principal play in the south of the study area and can While it has proven discoveries in the offshore, reservoir quality be attributed to multiple producing fields within the Springhill and continuity means that these are not commercial and further Formation. In many cases, charge relies on the structural offset prospectivity will be limited. of transgressive sandstones, which lie stratigraphically below • The Argentina Basin is unexplored but is interpreted to contain all the Lower Inoceramus source rocks. In the north, the play has a the necessary elements of a working petroleum system, although lower chance of success because the distribution and quality of with some uncertainty. Evaluation of the seismic data from a reservoirs remains uncertain. Potential risks are reduced at basin US Geological Survey legacy dataset (Triezenberg et al., 2016) margins where depths of burial are less. suggests that reservoirs in the form of turbidite channels, fans, and sandy contourites with strong Atlantic margin analogues are likely. Late Cretaceous turbidite play This unproven play interval exhibits significant potential, Summary although high levels of uncertainty persist, particularly regarding The regional screening process aims to assess a large area with source rock presence and maturity. The play is restricted to deep a goal to better understand the regional distribution of viable shelf and deep-water areas in the Argentina and Malvinas basins petroleum system elements and where these might constitute a and is controlled by both reservoir and charge extents. The spatial working hydrocarbon system. distribution of source rocks is poorly understood, and maturity This regional evaluation has been performed through the models are poorly constrained because of a lack of calibration collation of legacy datasets, available from publicly available data and thermal boundary constraints. Based on correlations sources, and illustrates the new insight gained from existing to the shelf and seismic analysis, the interpreted relatively datasets. Systematically collating and evaluating data in this way widespread presence of reservoirs is encouraging, although the helps to ensure that maximum value can be extracted from readily characteristics of any sand bodies is poorly understood. available public information to provide an informed evaluation of hydrocarbon prospectivity. Prospectivity implications Results from this study have presented areas of known Figure 9 shows a combined common chance segment (CCCS) potential, such as the Malvinas and Austral basins, that hold map incorporating the results of all assessed plays. This has the promise for underexplored play types as well as highlighting following implications for prospectivity in the region: areas previously unsuccessful or that have undergone limited or • The Austral and Malvinas basins have proven play fairways and no exploration to date. With the impending licensing round for are likely to contain further resources at various play intervals. offshore Argentina, regional screening provides the exploration Prospectivity decreases towards the southern portion of the geologist with a head start in assessing this frontier province.

Figure 8 Basic workflow employed to carry out regional screening for the Argentine margin. Combination of a series of common chance segment maps forms a composite common chance map that assesses the effectiveness and presence of all petroleum system elements and their relative juxtaposition.

52 FIRST BREAK I VOLUME 36 I MARCH 2018 SPECIAL TOPIC: PETROLEUM GEOLOGY

Figure 9 CCCS map in DecisionSpace Geosciences that displays the predicted areas with a higher chance of success for all three plays assessed on the Argentine margin. Potential has been highlighted in the Austral/Malvinas basins in the south as well as the Argentina Basin to the northeast. A lower chance of success is noted in the Colorado and Salado basins, although more detailed assessments of specific play elements could be seen to lower interpreted potential risk in these basins.

Too often industry decisions need to be made quickly; regional y Recursos Naturales de la Plataforma Continental Argentina screening results, like these presented, provide the explorationist (Geology and Natural Resources of the Continental Shelf Argentina), with a quick appreciation of the region’s geology and where 135-156. potential might and might not exist. Galeazzi, J.S. [1998]. Structural and Stratigraphic Evolution of the Areas identified with a higher chance of play success warrant Western Malvinas Basin, Argentina. AAPG Bulletin, 82 (4), 596-636. further investigation, and uncertainty in some parts of the Hodgson, N., S. De Vito, K. Rodriguez and M. Saunders [2017]. Argen- evaluation could be significantly decreased with additional data. tine Basin: the new search for oil in one of the least explored basins Licensed multi-client seismic data are already available for the on planet Earth. First Break, 35 (11), 97-101. Austral and Malvinas basins, and new seismic data has recently Legarreta, L. and H.J. Villar [2011]. Geological and Geochemical Keys of been acquired in the Argentina Basin and the Austral/Malvinas the Potential Shale Resources, Argentina Basins. AAPG Geoscience area. This seismic data will provide more robust depth control Technology Workshop, AAPG Search and Discovery, 80196, 1-20. across the study area, allowing for further improvement in burial Loegering, M.J., Z. Anka, J. Autin, R. di Primio, D. Marchal, J.F. prediction of potential source intervals, particularly the Aptian, Rodriguez, D. Franke and E. Vallejo [2013]. Tectonic evolution of and consequently for source rock maturity. Additionally, on the the Colorado Basin, offshore Argentina, inferred from seismo-stratig- completion of detailed seismic mapping, a greater appreciation raphy and depositional rates analysis. Tectonophysics, 604, 245-263. for reservoir distribution and play extent would help us to better Naafs, B.D.A., J.M. Castro, G.A. De Gea, M.L. Quijano, D.N. Schmidt understand and evaluate the chance in these basins. Hodgson et and R.D. Pancost [2016]. Gradual and sustained carbon dioxide al. (2017) demonstrated that the new data shows further evidence release during Aptian Oceanic Anoxic Event 1a. Nature Geoscience, of source and reservoir horizons, providing more encouragement 9, 135-139. for potential prospectivity and continuing to justify industry Otis, R.M. and N. Schneidermann [2000]. A failed hydrocarbon system interest in the upcoming acreage releases. - Rawson Basins, Argentina. In: M.R. Mello and B.J. Katz (Eds.), Petroleum Systems of South Atlantic Margins, AAPG Memoir, 73, References 417-427. Autin, J., M. Scheck-Wenderoth, M.J. Loegering, Z. Anka, E. Vallejo, Pángaro, F., V.A. Ramos and P.J. Pazos [2016]. The Hesperides basin: J.F. Rodriguez, F. Dominguez, D. Marchal, C. Reichert, R. di a continental-scale upper Palaeozoic to Triassic basin in southern Primio and H.-J. Gotze [2013]. Colorado Basin 3D structure and Gondwana. Basin Research, 28 (5), 685-711. evolution, Argentine passive margin. Tectonophysics, 604, 264- Rodriguez, J.F. and M.J. Cagnolatti [2008]. Source Rocks and Paleogeog- 279. raphy, Austral Basin, Argentina. American Association of Petroleum Bushnell, D.C., J.E. Baldi, F.H. Bettini, H. Franzin, E. Kovas, R. Mar- Geologists (AAPG). inelli and G.J. Wartenburg [2000]. Petroleum systems analysis of the Rystad Energy [2017]. NASWellCube, version 2017-07-12. Digital Eastern Colorado Basin, offshore Northern Argentina. In: M.R. Mello dataset. and B.J. Katz (Eds.), Petroleum Systems of South Atlantic Margins. Schwarz, E., G.D. Veiga, L.A. Spalletti and J.L. Massaferro [2011]. The AAPG Memoir, 73, 403-415. transgressive infill of an inherited-valley system: The Springhill Figueroa, D. [2010]. Perspectivas Exploratorias en el Offshore de Formation (lower Cretaceous) in southern Austral Basin, Argentina. Argentina. Congreso de Produccion del Bicentenario Salta, Marine and Petroleum Geology, 28 (6), 1218-1241. Presentation. Tissot, B., G. Demaison, P. Masson, J.R. Delteil and A. Combaz [1980]. Fryklund, B., A. Marshall and J. Stevens [1996]. Cuenca del Colorado Paleoenvironment and petroleum potential of Middle Cretaceous (Colorado Basin). In: V.A. Ramos and M.A. Turic (Eds.), Geologia black shales in Atlantic basins. AAPG Bulletin, 64 (11), 2051-2063.

FIRST BREAK I VOLUME 36 I MARCH 2018 53 SPECIAL TOPIC: PETROLEUM GEOLOGY

Triezenberg, P.J., P.E. Hart and J.R. Childs [2016]. National Archive of Van Der Spuy, D. [2003]. Aptian source rocks in some South African Marine Seismic Surveys (NAMSS): A USGS data website of seismic Cretaceous basins. In: T.J. Arthur, D.S. Macgregor and N.R. Cameron reflection data consisting of data acquired by or contributed to U.S. (Eds.), Petroleum Geology of Africa - New Themes and Developing Department of the Interior agencies. US Geological Survey Data Technologies, Geological Society of London - Special Publications, Release, US Geological Survey (USGS). 207, 185-202.

ADVERTISEMENT

EAGE Workshop on 4D Seismic and Reservoir Monitoring Bridge from known to unknown

18-20 November 2018 – Abu Dhabi, UAE

We invite practitioners, innovators and dealmakers to come to this workshop to share their achievements and challenges, lay out big innovative ideas and seek new alliances to break into unknown territory.

Topics • 4D Seismic acquisition, processing, interpretation – Spread the best practices learnt over more than twenty years on Clastics and Chalks • 4D Seismic feasibility, acquisition, processing, interpretation – Explore emerging territories (Land, Carbonates, Uncon ventional) • Other monitoring technologies (microseismic, borehole, INSAR, non-seismic etc) • Assimilation of 4D data with other reservoir data • Reservoir Management using data from Monitoring Tech nologies • New technologies to make 4D seismic practical and eco nomical on giant reservoirs

www.eage.org Call for Abstracts is Open Now!

54 SRMW18FIRST V2H.indd BREAK 1 I VOLUME 36 I MARCH 2018 13/02/18 09:01