Mavromatidis Kelessidis Monopolis Amireg04-1

8/11/2019 Mavromatidis Kelessidis Monopolis Amireg04-1

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A review of recent hydrocarbon exploration in Greece and its potential

A. MavromatidisTechnological Educational Institute of Crete, Dept. of Natural Resources & Environment, Chania,

Greece

V. C. KelessidisTechnical University of Crete, Dept. of Mineral Resources Engineering, Chania, Greece

D. G. MonopolisTechnical University of Crete, Dept. of Mineral Resources Engineering, Chania, Greece

Paper presented at the 1st International Conference on Advances in Mineral Resources Managementand Environmental Geotechnology, 7-9 June 2004, Chania - Crete Greece

ABSTRACT

The paper reviews the recent explorationactivity of hydrocarbons in Greece andneighbouring Albania and Turkey. Emphasisesthe relevance of the prospects in theseneighbouring countries and those identified inGreece, and finally accentuates the importanceof a new exploration strategy in Greece. With

only few deep exploration wells drilled the lastyears, none offshore, the area should be set for amore extensive exploration effort and a futureannouncement for a new onshore and/oroffshore licensing round by the new Greekgovernment should be pursued.

1. INTRODUCTION

Hydrocarbon (HC) exploration in Greece hasbeen under way from the 1860s. Acomprehensive review for the activity until

1977 has been done by Monopolis (1977) anduntil 2000 by Xenopoulos (2000). Earlyexploration focused on the abundant surfaceseepage of oil in the area of western Greece.Then, after decades, in 1972, it focused in thePrinos area northeast of the country, in 1980s insouth western Greece at the Katakolon area andfurther north in Epanomi area and finally in2000s again in western Greece. Explorationresults to date are not encouraging since onlyone viable field was discovered, in Prinos area,

while the small offshore and onshore oil and gas

fields in Katakolon and the gas field in Epanomihave not yet been developed. It is worthmentioning that in Albania there are about 25oil and gas fields while in Turkey there are morethan 16 oil and gas fields in Thrace basin andfew in central west Turkey. Based only on

published data a connection between the provenfields in neighbouring countries around Greeceand the potential of the explored areas in Greece

is attempted in this paper. The approach canhelp establish the relationship betweentectonostratigraphic basin evolution and

potential resources and can assist inprospectivity assessment.

2. IONIAN ZONE, ALBANIA ANDWESTERN GREECE

2.1 Albania

The Ionian zone is the main HC producing

region in Albania with recoverable reserves inTertiary clastic and carbonate reservoirs (Fig.1). These include giant heavy oil fields with lowrecovery factors such as the Patos-marinza fieldwhich has approximately 2 billion barrels in

place (Albpetrol, 1993). The zone has a well-developed Tethyan stratigraphy reaching a totalestimated thickness of 10 km or more (Velaj etal., 1999). OMV is the biggest international

player in onshore Albania. OMV has alsolicenses in the Patos-Marinza field and offshore


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Albania block (http://www.omv.com).Geophysical surveys have attested the highly

prospective carbonate reservoirs. This deepcarbonate section, overlain by evaporates, holdsthe potential for future discoveries in Albania(Nieuwland et al., 2001).

2.2 Western Greece

The Greek Ionian zone area, should be active oilor gas province since there are oil seepsdistributed in various locations and is acontinuation of the proven Albanian fields (Fig.1). However, the only proven discovery is theoil-gas field offshore in Katakolon area. Thefield discovered in 1981, and the producinghorizon is the Eocene-Cretaceous carbonates of

a paleostructure, unconformably covered by

Figure 1. Licensing status and exploration activity in Albania, Greece and western Turkey. Major tectonic zones,

exploration blocks, oil and gas fields, major oil seeps and recent drilled wells in Greece are also shown (Ait =

Aitoloakarnania, Ap-1 = Apollo-1, Ar-1 = Artemis-1, De-1 = Demetra-1, Ev-1 = Evinos-1, Ion = Ioannina, NWP

= Northwest Peloponnesos, TS-1 = Trifos South-1).


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clastic Neogene sediments (Roussos &Marnelis, 1995) with an estimated 40 million

bbl oil in place and 10 to 12 million bbl

recoverable oil (Maniatakis & Stabolis, 2003).The Ionian zone is composed of Tertiary clasticsthat underlain by thick Mesozoic carbonateswhich in turn are underlain by Late Triassicevaporites. All exploration wells have stoppedin or never reached the Late Triassic evaporiticsection which has never been penetrated.Triassic evaporites consist of halite, gypsum,and anhydrite with interbedded dolomite andthin organic rich shales. The original thicknessis uncertain but estimates raise it to more than

2000m (IGRS, 1966; Mavromatidis, 2004). Ontop of this lie the carbonate successions ofPantokrator limestones which are more than1500m thick (IGRS, 1966). Hence, the aim forfuture exploration and the potential for oil orgas discovery should be at locations with totalsection thickness of more than 3500m or morethan 2000m in case drilling starts from surfaceevaporites.

Exposed or shallowly buried carbonateanticlines are present throughout the Ionianzone. These carbonates, limestones with tight

matrix porosity, which are abundant across thearea, are not expected to form effective seals asthey are unlikely to have escaped bacterialdegradation and fracturing during Tertiarycompression (Mavromatidis, 2004). However,the traps below the evaporites, the deep playsare particularly attractive. These are the deeply

buried clastic and carbonates that may havefortified from bacterial degradation so that goodquality of hydrocarbons may have been

preserved (Mavromatidis, 2004). Such traps are

evident in southern Albania (Velaj et al., 1999;Nieuwland et al., 2001).

In late 1995, the Greek state oil companyHellenic Petroleum (HP) announced for the firsttime after 1980 an international tender for sixregions of western Greece (Fig. 1) (three onland and three offshore), for a total area of12139 km2. The Katakolo field has beenincluded in the tendering process but there wasinterest only on exploitation without the

preceding exploration stage, required by thetender and thus the Greek state did not

proceeded further (Maniatakis & Stabolis,

2003). In 1997, the government signed fourcontracts for oil exploration and exploitation infour stretches near Ioannina and the northwest

Peloponnesos (NWP), two of them betweenEnterprise Oil and the Greek State (HP) and theother two contracts in Aitoloakarnania and Gulfof Patraikos, between Triton Ltd. and the GreekState (HP). Enterprise Oil, in its twoconcessions has carried out geophysicalresearch which covered 700 km of seismic lines.The processing and interpretation of the seismicreadings in the NWP has led to thedetermination of the position of two drillingsites at a depth of 2500m each, while for

Ioannina has led to the determination of theposition of one well for a target depth of about4000m. Triton Ltd. has also carried out a broad

programme of seismic tracings on the land areaof Aitoloakarnania which has led to thedetermination of the position of two drillingsites, one at Evinos at a depth of approximately1500m and a second one in the Trifos area, atabout the same depth. In the sea area of the Gulfof Patraikos, Triton Ltd. has carried out seismictracings of 1000km, with 4000m of cables (longoffsets method). The processing and

interpretation of these tracings aimed at atargeted depth of 3000m below sea level.

By late 2001, all exploration and drillingactivities finalised in a grotesque manner.Enterprise Oil drilled two wells in NWP,Artemis-1 and Apollo-1 in the year 2000, andone well, Demetra-1, in the Ioannina area,drilled in 2001.

Artemis-1 is located on a faulted fold with atop seal of Oligocene flysch. The target was theIonian basinal carbonates underneath the flysch.

The reservoir interval was prognosed to consistof fractured carbonates of Late Cretaceous toEocene age which are productive further upnorth in Albania and in the central Adriaticfields offshore Italy. Drilling proceeded to atotal depth of 2375m. The well encounteredsome oil shows and the well was plugged andabandoned (P&A).

The Apollo-1 well was located in theGavrovo Zone, within the Hellenide fold andthrust belt. The structure targeted by the Apollo-1 was a faulted fold, having the flysch as a sealrock. Only two key lithological intervals were


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present in the well, namely the Flysch and theGavrovo carbonates, the latter that comprise thereservoir. The Gavrovo carbonates have rarely

been drilled in Greece. The reservoir intervalwas prognosed to consist of fractured andkarstified platform carbonates, analogues ofwhich are productive in the greater Adriatic andsouthern Italy region. The well proceeded to atotal depth of 1710m and was P&A.

The Demetra-1 well was drilled in 2001.Original target depth for Demetra-1 well was at4000m aiming at penetrating the thickevaporitic section never penetrated before butthis also did not materialize in this attempt. A

dome structure was delineated from seismicprofiles at that depth and the well was spuddedand drilled over a period of five months and

preceded with no significant problems.However, it did not succeed in penetrating theevaporites with reports indicating that drillershad encountered unexpectedly high pressures,while still in the evaporitic section, which

proved impossible to overcome, even after theunsuccessful attempt to sidetrack the well.These problems increased the drillingexpenditure significantly and combined with the

acquisition of the operator (Enterprise Oil) byShell, a shift of priorities of the new owner ledto the decision for the well to be P&A.

In 2000, Triton Ltd. drilled two wells inAitoloakarnania, named Trifos South-1 andEvinos-1. Triton Ltd. did not execute the agreeddrilling program in the Gulf of Patraikos due tocompanys management decision after thetakeover by Amerada Hess.

Trifos South-1 was planned to drill to a targetof Ionian Zone basinal carbonates, sealed by

Oligocene flysch. This reservoir/seal intervalwas prognosed to be in a subthrust setting,overthrust by Triassic evaporites. However,during drilling these evaporites were found to bethicker and the well stopped within theseevaporites at 1509 m. Commitment depth forthe well was 1500 m. This well failed to drill tothe objective reservoir and failed to test the

play. It was P&A (with minor oil and gasshows).

Evinos-1 was planned to drill Gavrovo Zoneplatform carbonates, sealed by Oligoceneflysch. The well was drilled to commitment

depth of 1500m and stopped at 1508m. Minorgas shows and poor oil shows were encounteredin the basal flysch and within the carbonates and

the well was P&A. The most likely cause fordry hole is absence of trap at the well location.

Even though the recent activity in westernGreece has proven unsuccessful, the wealth ofsubsurface data that has been acquired with stateof the art technology, never done before at theselarge depths, as in Demetra-1, should be madeavailable for further investigation and analysisso that a better picture of western Greecesubsurface geological setting to be drawn andthe causes of the unexpected high pressures to

be determined. This will aid in the delineationof future attempts for oil exploration whichshould not be ceased.

3. GRABENS IN WESTERN TURKEY ANDMESOHELLENIC TRENCH IN CENTRALGREECE

3.1 Grabens in western Turkey

In an extensional regime in western Anatolia(Turkey), E-W grabens formed during the

Pliocene and locally intersected older Mioceneformed grabens that contained lacustrine

bituminous shales and fan delta sediments(Yilmaz & Gelisli, 2002) (Fig. 1). The AlaehirGraben is an example of such configuration. Itcontains possible traps as well as high potentialfor HC generation. Geochemical analyses showthat Early-Mid Miocene lacustrine shales arecapable of producing oil (Yilmaz & Gelisli,2002).

3.2 Mesohellenic trench in central GreeceThe Mesohellenic basin trends SSE-NNW is130km long and 40km wide and is located in thesub pelagonian zone (Fig. 1). Two depocentres,more than 4200m and 3200m thick, have beenrecognized of Middle Eocene to MiddleMiocene age, where submarine fans ofsandstones and shales have accumulatedunconformably over a sub pelagonian complex.Source rocks and possible stratigraphicallytrapped reservoirs have been identified with

geochemical analyses (Kontopoulos et al., 1999;


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Avramidis et al., 2002). All indications from thearea however show that the organic matter isimmature and thus the generation of gas is of

biogenic origin.

4. THRACE BASIN, NORTHWESTERNTURKEY AND TERTIARY BASINS,

NORTH AND EASTERN GREECE

4.1 Thrace Basin, northwestern Turkey

The Thrace basin located in European Turkeycovers an area of some 20000 km2. It hasdeveloped as a fore-arc basin between themedial Eocene to Oligocene. The basin is filledwith turbidites in its interior and clastics andcarbonates on the margins (Grr & Okay,1996). Further south in the Saros Gulf there is a

producing oil and gas field (Coskun, 2000).Exploration has mainly targeted deep plays

in Eocene age sediments which resulted inseveral discoveries. Currently there are 14commercial gas fields and 3 oil fields. A recentdiscovery is the Gocerler gas field, a discoverymade from shallower Oligocene sediments(http://www.amityoil.com.au). Major explorer is

Amity Oil which holds seven explorationlicences in the area together with TurkiyePetrolleri Anonim Ortakligi and OmaxResources.

4.2 Tertiary basins, north and eastern Greece

In eastern Greece exploration was orientedtowards the post-orogenic Paleogene andyounger Neogene basins. The main tectonicregime that controlled their evolution wasextensional. The stratigraphy includes Eocenereefal limestones, thick Eocene to Oligocenemarine clastic sediments, and Neogeneterrigenous deposits with extended Messinianevaporites.

Potential source rocks for gas and oilgeneration have been discovered in Eocene andMiocene sediments. Traps include rolloveranticlines, faulted structures, and stratigraphicfeatures in Eocene reefal limestones, EoceneOligocene sandstones, and Neogene sands.Trapping ability also exists in fractured

Mesozoic formations (Fig.1), although they are

not source rocks but oil comes from lateralmigration from younger formations. TheEpanomi gas field was discovered in 1988 by

HP, with recoverable reserves of 0.5 billionNm3 of natural gas (Maniatakis & Stabolis,2003). The structure is formed by the

paleoerosional surface of Mesozoicmetamorphic limestones buried below Tertiaryclastic sediments (Roussos & Marnelis, 1995).The field has not been explored to date.

Miocene sands, capped by thick salt andevaporite sections, form the reservoir for Prinosfield. Source rocks were considered to bemarine shales of Upper Miocene age. The

Prinos structure is a graben bounded by sealingfaults which dip towards the center of the basin.The Prinos oil and South Kavala gas fields werediscovered by the Oceanic company in 1973 andexploited by North Aegean Petroleum Company(NAPC). Production terminated in 1993 for theSouth Kavala field and 1998 for the Prinos field.However, a new oil field, namely North Prinos,was discovered in 1994 by NAPC, with HP

participating with a 35% interest Maximumproduction was estimated at 3,000 barrels per

day. In 1999, NAPC withdrew from the regionand operation has since been undertaken by thenewly formed Kavala Oil.

There is recent exploration activity in thePrinos area, undertaken by the operator, KavalaOil. Information has been collected from newsagencies and company announcements since noscientific information is publicly available. Awell was drilled in the E1A prospect in June2000 and two producing zones were discoveredat a depth of around 2900m. Although tests haveshown that it contained much less H2S that theoil produced from Prinos and with estimates ofrecoverable reserves of about 13 million bbl(Kavalanet, 2002), it was a very tight reservoirrequiring hydraulic fracturing. In addition, the

building of an exploitation platform should havebeen necessary, with an investment of around50 million US$, since it was further away fromthe existing platforms. Exploitation was thusdeemed non attractive because of economic

situations at that time and has thus been


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postponed for later years. In October 2003 therewas the buyout of the major shareholder ofKavala Oil (Eurotechniki) by Regal Petroleumwhich now holds about 60% of Kavala Oil.Following the buyout, a well was drilled in

November 2003 with a cost of 8,5 million US$in the Kallirachi prospect, which logged a 200mgross pay zone with 61m of sweet oil net pay ata total depth of 2556m. Although no results ofany well testing have been officially reported,independent consultants pre-drill estimatesshow a maximum of around 227 million bbl ofrecoverable oil, (Kavalanet, 2003; Oil&Gas J.

Online, 2004). The announced discovery isexpected to spur drilling activity with probablyfour to five wells and an investment of around150 million US$ already announced, raisingmore the expectations for further drillingactivity (Kavalanet, 2003). However, there areno plans for extending the exploration activityto the potentially hydrocarbon bearingreservoirs in the areas east of the island ofThassos.

5. DISCUSSION

It is obvious that the exploration success inGreece for finding HC till present time is notvery encouraging regarding further exploration.The majority of the wells, drilled before 90s,were selected mainly on the basis of surfacegeology with poor geophysical support.Geological surveys although locally controlled

by some rather deep wells (> 3500m) have notyet been capable of providing a comprehensiveand reliable picture of the relatively deepgeological structure.

However, in western Greece there are basinswith significant HC potential and merits forexploration. All requirements for hydrocarbonaccumulations are satisfied in the Ionian basin,namely source rocks (Rigakis & Karakitsios,1998), oil generation (Mavromatidis, 2000),reservoir, seal rocks and palaeorelief trapstructures (Zelilidis et al., 2003). In this areathere is significant amount of geological data.This part of the country has already attracted oil

exploration interest since early in this century

and has been covered by detailed surfacegeological surveys including mapping of1:50000. Western Greece is covered by

northwest-southeast trending geotectonic unitsconstituting the southern prolongation of the oil

producing Albania (Fig. 1). It can be safelystated that there is a great possibility forcommercial production to be established inwestern Greece which is an area of active oilseeps, asphalt saturated strata, repeated shows inwells and thick dark coloured bituminouscarbonate rocks.

In Katakolon, exploration has proven theexistence of the oil field, in water depths of

more than 200m, which awaits nowexploitation. This should proceed with theappraisal and development wells. While thistask at the time of its discovery was deemedvery risky and difficult and therefore notundertaken, now with the recent technologicaldevelopments and why not, the breakthroughs indrilling technology, for deep well drilling(Jenkins & Roger, 1995; Judzis & Baowes,1997), for extended reach wells (Cruse et al.,1997; Avignon & Simondin, 2002), and with theless expensive Coil Tubing Drilling (CTD), the

water depths of 200m are tractable leading tothe suggestions for revisiting the prospects inKatakolon (see Kelessidis & Mpandelis, 2003,for listing of CTD activities around the worldand Konstantakopoulos et al., 2000, for anoverview of CTD). Similar statements wereexpressed before (Xenopoulos, 2000), whoclaims further that based on data analysis fromseismic and well profiles (available until theyear 2000), there were good chances fordiscovering more oil not only in western Greece

but in other areas of Greece as well.The Messohelenic basin is considered to be a

very high risk area for HC exploration in whichno commercial discoveries have yet been made.One may be tempted to think of similarities withthe Alaehir graben where there is evidence forHC generation. But this is not true sinceAlaehir Graben is not in the subpelagonianzone and the two areas have not the samegeological background. Hence, theMessohelenic basin should be a region withvery low exploration priority.

The Epanomi gas field has similarities with


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the gas fields in Thrace Basin, one is thelithology and the second is the tectonic

province. The Thrace Basin, which is underintensive exploration activity at the moment, isan extension of the Axios-Perirodopic zone inGreece where the Epanomi oil-gas field belongsto. The Prinos field has also similar lithologywith Thrace Basin units and some claim that gasfields in Marmara Sea in Turkey produced fromthe same carbonates as in Prinos oilfield(Coskun, 2000).

6. CONCLUSIONS

Is there plenty of oil or gas in Greece and will itever be found? It is the ever-occurring questionto every Greek since the beginning of the 19 thcentury when oil was crowned as the king ofenergy source. University of Athens professorGeorgalas starts his 1937 inaugural lecture withthis same question and goes on saying ofcourse there are hopes for existence of oil andgas fields in Greece stemming from scientificdata but to answer this question fully we mustdo a lot of drilling (Monopolis, 1977). Today,

this question has yet to be answered and ifposed we would answer it exactly the same way,even though ever since 1937 there have beenmore than 200 wells that have been drilled (withabout 60 of them in Prinos field, of which about40 are production and injection wells). Thisdrilling activity resulted in the discoveries ofPrinos, Katakolon and Epanomi fields. This lowlevel activity leads us to claim Greece as theleast explored country not only in theMediterranean region but also in central,

northern and eastern Europe as well.Many factors have contributed to this lowexploration activity in Greece, from the smallsedimentary basins, both onshore and offshore,to the large water depths offshore. Currentdrilling technology enables the successful

penetration in the deep horizons where oil orgas is premised to be, as analyzed above, as wellas to large water depths for offshoreexploration. All countries neighboring Greeceexceed Greece in daily oil production. Thegeologic setting in all these countries is both

similar and indicative of containing commercial

oil accumulations.The licensing round held in 1996, the first

one after 1980, awarded six concessions and

none of these prospects materialized. In May2002, Greece announced that it would hold itssecond oil exploration licensing by early 2004.The round would aim to include both offshoreand onshore areas in north-western and south-western Greece, plus unexplored blocks in theIonian Sea (http://www.aapg.org, http://www.eia.doe.gov). However, as of March2004, no such undertaking has occurred when atthe same time all countries in southMediterranean area (e.g. Albania, Bulgaria,

Croatia, Egypt, Israel, Italy, Libya, Malta,Serbia-Montenegro, Romania, Syria, Turkey)have provided licences to oil companies andexploration projects are on progress.

An aggressive oil exploration campaignshould thus be undertaken in the immediatefuture. Exploration should be undertaken withstrong commitment from the Greek State, whileexploitation should be left for third parties(Monopolis, 1989). What is necessary is thecommitment of the new Greek government thatit will pursue the exploration and exploitation

activity with new licensing rounds, andremembering the golden rule for discovering oiland gas fields, that is, unless we drill we willnever find out what is in the subsurface.

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Mavromatidis Kelessidis Monopolis Amireg04-1