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EAGE/AAPG Workshop on Reducing Exploration Risk in Rift Basins
- Conference date: August 26-27, 2019
- Location: Kuala Lumpur, Malaysia
- Published: 26 August 2019
1 - 20 of 23 results
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The successful discovery path: from Mozambique to Sri Lanka
Authors C. Tu and M. FrancisSummaryThe prospective East Africa passive margin is attracting hydrocarbon exploration. This study investigates new geophysical data from Mozambique and Sri Lanka that aid our understanding of this stage of the Gondwana breakup. We review seismic, gravity, and stratigraphic data in the Southern Lanka Basin, a likely conjugate to the Mozambique Channel and Rovuma Basin. We observe the opening of two oceans linked by a transform zone along the Davie fracture zone. During this transit, Madagascar, the southern tip of India, Sri Lanka, and Antarctica were all connected. Multiclient 2D and 3D data offshore Mozambique provides knowledge of sedimentation processes during the breakup of Gondwana. In summary, new exploration data helped refine the fit, rifting, and subsequent movements of the tectonic plates during the Gondwana breakup. This knowledge, combined with additional data, reprocessing, and interpretation add further constraints to the regional petroleum system models, thereby reducing hydrocarbon exploration risk.
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Structural Controls on Rift Basin Depositional Systems
By R. ShoupSummaryThere are three archetypal rift basin geometries: asymmetric half grabens, symmetric sags and grabens, and compound basins. The basin geometry in turn imparts a fundamental control on the distribution of the various depositional systems within the rift . Outcrop observations in several Triassic rift basins in north eastern Thailand combined with well, core, and depositional environment maps from twenty six Tertiary rift basins in Southeast Asia indicate that the distribution of synrift lacustrine source rocks and reservoir sequences are remarkably similar in continental rift basins. In that the relationship of the depositional systems to the basin geometry is highly predictable interpreters have the means to define the elements of the rift basin’s petroleum system.
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THE EAST AFRICAN RIFT SYSTEM AND ITS APPLICATION AS A PETROLEUM ANALOGUE
More LessSummaryThe East African Rift System (‘EARS’) is arguably the most studied rift system in the world, though until this century, the interest in the system was largely academic, with subsurface knowledge being poor. There was previously a perception that the system was too young to form effective petroleum provinces. Since 2005, however, there have been a number of somewhat unusual oil discoveries that provide critical analogues for exploration around the world in similar tectonically dynamic systems. This drilling also for the first time enables us to understand the progressive development of the rift system through time. The discoveries show that with a very young and highly active petroleum system, unusual lithologies and fault gouges can act as highly effective seals. Also, in such settings, hanging wall trap settings are as effective as footwalls.
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Sequential fault movement and sequence stratigraphic implications on linked depositional systems in a multi-phase rift, Central and Southern Taranaki Basin, New Zealand
Authors Alexander Wunderlich and Jan MayerSummaryThe economically important synrift successions of the Late Cretaceous sediments in the Taranaki Basin are directly linked and influenced by tectonic activity. Accordingly, it is important to understand how this tectonic subsidence is affecting the architectural signature diagnostic of synrift basin fills in order to develop predictive models for synrift plays. The interaction of sediment supply and accommodation space determines the evolution of depositional systems in synrift settings and have been discussed in a series of studies (Leeder and Gawthorpe, 1987; Prosser et al., 1993; Gawthorpe et al. 1994; Ravnas and Steel, 1998). However, the influence on accommodation creation and stratal architecture during repeated times of tectonic episodes, alternating with extended periods of tectonic quiescence is the setting up a complex basin architecture. This wide range of depositional environments over time as a relationship between sediment supply, sea-level and subsidence shift, is less well understood in multiphase rifts then in single rifts (e.g. Ravnas et al, 2000).
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De-risking a frontier Cretaceous rift basin by oil show geochemistry, its implication on syn-rift sedimentary architecture and hydrocarbon phase assessment – an example from the Canterbury Great South Basin, New Zealand
Authors Jan Mayer and Alexander WunderlichSummaryThe Canterbury Great South Basin (CGSB) is a 160,000 km2 frontier Cretaceous rift basin located off the east coast, South Island, New Zealand. Detailed seismic facies analysis and geochemical analysis of HC shows and cuttings were used to evaluate the presence and characteristics of syn- and post-rift source rocks within the basin. The results were compared with samples from analogous basins and show strong similarities in between the basins. This study illustrates how a detailed geological assessment enabled a detailed analysis of the distribution of individual source rock intervals and their interaction with the tectonic processes within a frontier rift basin. Different source rock intervals developed during different stages of the rift system and are either proven by well penetrations or can be recognized via geochemical analysis and seismic facies analysis. These findings show the potential of this underexplored frontier basin and de-risks a giant drill ready basin centric prospect, which has been identified on 3D seismic, showing direct HC indications.
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Maturation of a new play concept in the older Pre Oligocene synrift section of Peninsular Malaysia Basin to rejuvenate exploration
Authors S.I. R Iyer, M.H. Damanhuri, A.A. Azman, N. Pendkar and F. IliasSummaryExploration for hydrocarbons in Malay and Penyu Basins located on the eastern offshore area of Peninsular Malaysia so far were focused mainly on the Oligo-Miocene to Pliocene stratigraphy consisting of Groups M to B. The remaining portfolio consists of small to medium size opportunities in subtle combination and stratigraphic traps. Efforts to rejuvenate exploration through play based evaluation and meticulous synthesis of previous drilling results resulted in the identification of a new play of Pre Oligocene age (Early Tertiary or Mesozoic) spread over the southwestern Malay Basin, the northern flank of Tenggol Arch, and the NE Penyu Basin. The new play concept was validated integrating seismic mapping, the results from reexamination of drill cuttings, comparison of interval velocities from wells with seismic, Bouger gravity and FTG interpretations. Prognosis of the petroleum system was based on evidences from an analog well in NE Penyu Basin. Several sizeable hydrocarbon prospects have been matured to test this play concept. The present paper discusses the characterization of this new play concept and its petroleum system with supporting evidence. Significant exploration opportunities along the western flank of Malay Basin can be unlocked by proving this play thereby rejuvenating the exploration in this mature basin.
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Synrift Play Potential - An Exploration Game Changer in the Cambay Basin
Authors R. Singh, B.N.S. Naidu, S. Somasundaram, N. Kumar and P. MohapatraSummaryThis paper is about syn-rift play correlation from Barmer basin to adjacent extended Cambay basin. Syn-rift plays are highly prolific in Barmer basin while poorly explored in Cambay basin, mainly because of huge post-rift potential. An attempt has been made to correlate syn-rift features of Barmer basin with Camaby basin in terms of hydrocarbon potential.
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Predicting fluid-flow controls in recycled orogenic sandstones: The Nyalau Formation, Onshore Sarawak Basin, NW Borneo
Authors E. Adepehin, C. Ali, A. Zakaria and S. SaliSummaryThe Nyalau Formation constitutes major Cycles I to III reservoirs in the offshore Balingian Province, Sarawak Basin, NW Borneo. Current understanding of its’ reservoir quality in the onshore Central Sarawak is relatively vague as previous works were focused mainly on outcrops studies. In this study, Cycle I sequences penetrated by a drilled well was studied to understand reservoir quality and predict fluid-flow controls. The reservoir units were sourced dominantly from recycled orogenic sandstones provenance (ROSP) and petrophysically tight (ɸ< 10%; K< 1mD) at shallow depth (1037 Feet), and the poro-perm datasets correlate to identified facies. Adopted realistic petrophysical model suggests that porosity loss resulted mainly from compaction with less contribution from cementation, as indicated by clustering of estimated 64.3% of the reservoir samples. This cluster has lost ca. 30 to 63% of their initial porosity due to mechanical compaction. Elemental and mineralogical datasets yielded useful downhole correlation with poro-perm variation. Early to intermediate diagenetic events characterise. Overall, our data imply that ROSP- sourced siliciclastic reservoir experience significant poro-perm loss at a relatively shallower depth. Hence, understanding reservoir provenance is essential to minimise exploration risks.
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THE KEYS TO SUCCESSFUL EXPLORATION OF THE SYNRIFT PLAY IN A CENOZOIC BASIN WITH A YOUNG PETROLEUM SYSTEM – A CASE HISTORY FROM THE KRA BASIN, THAILAND
Authors M. Minarwan, R.C. Davis, R. Utomo, T. Ampaiwan and W. PhaophongklaiSummaryA case history about hydrocarbon exploration of synrift play in the Kra Basin, northern Gulf of Thailand and lessons learned so far.
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Application of Sequence Stratigraphic Concepts to Unravel the Hydrocarbon Play Potential in Eocene Ardol Formation of Mature Cambay Rift Basin
Authors J.L. Konatham, S. Somasundaram, R.K. Singh, N.K. Singh, H.J. Bora and V. KolaSummaryThe Cambay basin is one of the most prolific oil and gas producing rift basins in India having discovered in place volumes >6 billion barrels with corresponding 2P reserves of ∼3752MMboe. This study addresses the Broach depression ( Figure1a ) in the southern part of the Cambay Basin where the Post-rift Mid-Eocene Ankleshwar Formation contains the majority of hydrocarbon producing reservoirs. In this basin, almost all the structural plays or conventional concepts have been tested and explored. To unravel remaining hydrocarbon potential, new concepts further than the conventional structural plays need to be strategized. In this paper we identify possibilities for finding stratigraphic prospects incorporating sequence stratigraphy to seismic interpretation and integrating well data. The Ardol Member in the study area has been mostly unnoticed owing to lack of structural traps. On the rising flank of the Tankari depression there is an absence of structural closure. A stratigraphic trapping concept is derived with lateral seals where the progradations terminate in the shale prone pro-delta area to the west, and coastal plain shales form a further boundary to the east. The well data also supports the increase in interspersed shales towards pro-delta zone.
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Reservoir characterization of Early Miocene to Pleistocene using seismic attributes: case study from Songkhla Basin, Gulf of Thailand
Authors Jidapa Phoosongsee, Christopher K. Morley and Angus J. FergusonSummaryDiscussion of syn-rift post rift transition in Songkhla basin, using 3D seismic and well data.
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Igneous intrusion in rift-related petroleum systems
Authors Chris Morley and Sopon PongwapeeSummaryDiscussion of igneous intrusions and their effects on petroleum systems in rifts.
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Role of Strike-slip Faulting in the Evolution of the Chumphon Basin, Gulf of Thailand
Authors Sarawute Chantraprasert, Jakkree Kongchum and Natapol KuenphanSummaryThe Chumphon Basin is a Tertiary basin on the western margin of the Gulf of Thailand. It is located at the northeastern tip of a NNE-SSW trending Khlong Marui Fault. The present study aims to document the relationship between the activities along the Khlong Marui Fault and structural evolution of the Chumphon Basin to test the strike-slip tectonic models for Tertiary basins in Thailand. The Khlong Marui Fault was a dextral strike-slip fault during the Cretaceous to Middle Eocene. It was subsequently superimposed by both sinistral and dextral motions. The Chumphon Basin is a half-graben bounded by an east-dipping ‘Boundary Fault’ and its geometry led to previous interpretation that it was developed as a pull-apart basin at the releasing bend along the Khlong Marui Fault. However, displacement variation along the Boundary Fault and thickness variation of basin fill argue against that interpretation. The Chumphon Basin experienced episodes of inversion during the Middle Miocene to Quaternary. Distribution of compressive deformation in the basin suggests that the inversion possibly resulted from restraining-bend deformation at the tip of the Khlong Marui Fault. During the inversion, existing oil accumulations were re-migrated and traps were breached by inversion-related faults.
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Exploration strategies turning a frontier to a prolific basin: A case study of Barmer Basin, India
Authors A. Mandal, S. Dasgupta and P. MishraSummaryBarmer basin has a rich history of exploration since 1995 with more than 20 years of drilling and acquisition of extensive data. Initial exploration strategy was to execute aggressive activities beyond the minimum work program commitments. New concepts and technology led to initial discoveries in the southern part of the basin and established the newly found lacustrine rift basin in the petroliferous province of western India. Most of the major discoveries were made during the first exploration phase, which were brought to development and subsequent production phase. The strategy adopted in the second exploration campaign is to chase the prospects with proven play extensions having the largest risked volumes. This campaign has unlocked tight oil potential and concluded with a total of 38 discoveries in the basin till date. The current prospect portfolio of >1 bn boe awaits an active drilling program to realize the yet-to-find potential of Barmer basin.
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Rifting to drifting with core complexes - The tectonic architecture & evolution of the Offshore Papuan Plateau, PNG
Authors A. Shakerley, C. Kergaravet, W. Gordon Canning, V. Bailly and J. RingenbachSummaryThis aim of this presentation is to show with modern, high quality seismic reflection data from the OPP, PNG, new insights into the tectonic architecture & evolution of continental core complexes; and raise the possible impacts of this style of rifting on subsidence history, heat flow, the spatial distribution of radiogenic, crust and on the sediments contained within the syn-rift section.
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Hunting Stratigraphic Pinch-Out Play: Exploration in Sirikit Mature Field, Thailand
SummaryThis abstract explains about stratigraphic trap exploration in the mature field. The team collaboration in play type identification, well targeting, excellent monitoring role while drilling, and future activity that can be broadened for the new opportunity.
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Paleogene Rift Basin Comparison of Sunda-Ardjuna-Jatibarang Basin and Its Implication for New Play Opportunities in Matured Field
Authors A. Aveliansyah and D. WahyuadiSummaryPertamina has signed a new contract of North West Java block, and will operate this 22,000 sq km area for the next 20 years. It is a mature area which has been explored for 50 years. All large conventional play have been produced, then a new play concepts are therefore needed to find a new significant resources. There are 3 main basins within this block; they are Sunda, Ardjuna, and Jatibarang Basin. It is a series of southern edge Sunda Craton that originated during a major Eocene-Oligocene period of dextral wrenching (Daly, et al., 1987). Eventough they were created by same process, but each basin has different play types. Sunda Basin has 80% oil productions from syn-rift interval (Oligocene Deltaic Sandstone Play); Ardjuna Basin, 85% oil productions are came from post rift (Miocene Shallow Marine Sandstone play); and Jatibarang Basin most of productive reservoir are came from early syn-rift interval (Oligocene Alluvial Fan Conglomerate Play). The comparison between those three basins would give useful play analogue for each other that need to be explored. Besides, there are also some new play opportunities in pre-rift interval that possibly give a new hope for big fish prospect in this mature field.
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Chasing Overlook Play Potential in Sirikit Mature Field, Thailand
SummaryThe Sirikit oil field is located in the Phitsanulok Basin. The dominant early exploration and development activities over 30 years were being focused in the structural closures which nowadays are scarce. Recently, the combination trap play type has been proven to be a major hydrocarbon (HC) contributor providing significant volume in this mature oil field.
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Petroleum systems and hydrocarbon potential of Vung May trough, Tu Chinh – Vung May Basin offshore Vietnam
More LessSummaryThe Tu Chinh – Vung May is a frontier basin offshore Vietnam. This study uses 1D and 2D basin modeling across the Vung May trough, a main trough SE of the Basin, to understand the petroleum systems and hydrocarbon potential of the area. The results indicate all the element of petroleum systems are favorable for the accumulation of significant hydrocarbon reserves.
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The Challenge Appraisal/ Development Journey to Unlock the Subsurface Model of Sarabop Formation Sirikit Oil Field, Thailand
Authors Anuttida Vesprasit, Che-azlan Chemong, Komon Pinyo, Kamonporn Inraikhing, Poonsawat Prachukbunchong, Teekayu Benjawan, Thitisorn Thitipattanakul, Thanyalak Sukha, Nutthaphon Ketklao, Wipasiri Jitmahantakul, Thanakit Chotpitayasunon, Chutchai Thiangtham, Spirit Pappring, Marut Wantawin, Kritsada Charoenniwesnukul, Ruthut Larpudomlert and Sakkaarin ChaisuriyapanSummarySirikit oil field is the biggest onshore oil field located in the Phitsanulok Basin. The field has been producing since 1982 that has lasted long for over 30 years. The primary target zones were produced from the lacustrine delta reservoirs with significant declining rate in past 10 years. Therefore, the several secondary target reservoirs were studied from years 2014 to 2018. Consequently, Sarabop formation, one of the complex secondary potential and common tight reservoirs, is being focused to be developed. Appraisal/Development strategy, drilling campaign and production schemes have been planned to effectively produce hydrocarbon from the formation as much as possible. With long term study from all subsurface information. The new Sarabop formation model of three members concept is created. The updated model give a significant improvement of the formation interpretation, especially in complex geological setting model. The updated model can assist the development plan such as more accurate well targeting and oil volume estimation. This move the project to be more accurate and be ready to advance work in near future as geomodelling and geomechanical modelling.
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