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1 eni s.p.a. upstream & technical services Master in Petroleum Engineering and Operations Congo & Angola Offshore-Congo River Basin Characteristics, exploitation approach and fields analogues Author: Yaregal Yenealem ASHEBIR San Donato Milanese 15 October 2014

2 Master in Petr.Engineering & Operations Congo & Angola Offshore-Congo River Basin Characteristics, exploitation approach and fields analogues Author Yaregal Yenealem ASHEBIR Company Tutors Colombi Nazzarena Piana Maurizio Division eni S.p.A. Upstream & Technical Services Dept. GAES/IPET University Tutor Prof. Francesca Verga services 2 San Donato Milanese 15 October 2014

3 Project Objective Introduction Reservoir characteristics and development of: pre-salt (Early Cretaceous) fields, post-salt (Late Cretaceous) fields and post-salt (Miocene) fields Risks and uncertainties on reservoir performance Conclusions List of Content Congo & Angola Offshore-Congo River Basin Characteristics, exploitation approach and fields analogues services 3

4 Project Objective Overall description of: stratigraphy, reservoir and fluid characteristics depletion mechanism and exploitation strategy Analogies among developed fields correlation of reservoir qualities (analogues) Analysis and identification of main risks/uncertainties. services 4

5 Project Objective Introduction Reservoir characteristics and development: pre-salt (Early Cretaceous) fields, post-salt (Late Cretaceous) fields and post-salt (Miocene) fields Risks and uncertainties on reservoir performance Conclusions List of Content Congo & Angola Offshore-Congo River Basin Characteristics, exploitation approach and fields analogues services 5

6 Introduction Congo Basin: Among the rift basins formed on the African and south American margin during late Jurassic-Early Cretaceous. Berriasian, 140My services

7 Tectono-Stratigraphy of Congo Basin Main Components of Passive Margin Congo basin evolution: Pre-Rift: Intial faulting (Fluvial and shallow lacustrine) Syn-Rift: Active graben development and different phase of subsidence (Lacustrine and turbidite and delatic/fluvial) Transitional: Cessation of crustal stretching of rifting Post-rift: Initial opening of the Atlantic Ocean and marine deposition. E. Beglinger, 2012 services 7

8 Generalized Stratigraphy of the Congo Basin and Petroleum system elements Source rocks: Early cretaceous lacustrine shales/marl and tertiary marine deep water shale/marl Reservoir rocks: Pre-rift early cretaceous lacustrine carbonate and sandstone Late Cretaceous (Albian-Cenomanian) shallow marine carbonate and sandstone Miocene deep water turbidites Trap: Faulted blocks, rollover anticlines/structures and growth faults Seals: shales and salts South Congo Basin (Angola) Stratigraphy North Congo Basin Stratigraphy Migration Pathways: Mainly fault related with vertical to sub-vertical pathways. Salt windows are also major migration pathway for post salt reservoir charge. services 8

9 Approximate field locations in southern and northern Congo basin Pre-salt fields (4) Post-salt Albian-Cenomenian fields (8) Post-salt Miocene fields (6) services 9

10 List of Content Congo & Angola Offshore-Congo River Basin Characteristics, exploitation approach and fields analogues Project Objective Introduction Reservoir characteristics and development of : pre-salt(early Cretaceous) fields, post-salt(late Cretaceous) fields and post-salt(miocene) fields Risks and uncertainties on reservoir performance Conclusions services 10

11 Characteristics and Analogies between Pre-salt (Early cretaceous) fields Pre-salt reservoir in Congo basin (Angola) The pre-salt structural setting controls the lacustrine carbonate development and its hydrothermal diagenesis Reservoir: Lacustrine limestone and dolomite carbonate Reservoir quality varies mainly due to: Structural/regional controling factors Enviromental and climatic controling factors Diagenetic Control (Dolomitization) Field Avg. Phi % Sw % K md API µ rc A B Porosity versus permeablity services 11

12 Characteristics and Analogies between Pre-salt (Early cretaceous) fields Pre-salt reservoir in Congo basin (Congo) Field C Trough Well-2 Field D Well-1 Reservoir: Lacustrine turbidite sandstone Fluid type: Gas, Condensate and Oil Petrophysical variation is due to different sediment source area in the basin Field Phi % Sw % K md API µ rc C D services 12

13 Development of Pre-salt Fields Pre-saltreservoir in Congo basin(angola) Natural depletion with gas lift Acid stimulation to improve production. Toca carbonate reservoir varies field to field mainly due to the complex depositional and diagenesis history Field OOIP (MMBO) Reserve (MMBO) RF % A B Comparison between different pre-salt carbonate fields are difficult. Pre-saltreservoir in Congo basin(congo) Natural depletion with gas lift The pre-salt lacustrine turbidite sandstone are comparable in rock properties and fluid type. Horizontal multi frac leads to strong increase of well productivity as the reservoir is tight sandstone. Field OOIP (MMBOE) Reserve (MMBOE) RF % C D services 13

14 Characteristics and Analogies between Postsalt (Albian-Cenomanian) fields Albian-Cenomanian formations in Congo basin characterized by interbedded sandstone, dolomite and limestone that was deposited as alternating Transgression-progradation depositional facies. Pinda/sendji depositional Model Angola Congo Fields Reservoir Phi % K md API A B Viscosity rc Pinda ? Vermelha Pinda ?? Vermelha (Pb) C Pinda D Sendji Sendji and E Tachla F Sendji G Sendji H Sendji services 14

15 Development of Albian-Cenomenian fields Drive Mechanism: Two phases First Phase: Natural depletion and Second Phase: water injection when pressure start depleting. Most development wells produces with ESP. Angola Congo Fields Reservoir OOIP (MMBO) Reserve MMMBO RF % Recovery Mechanism A Vermelha Natural depletion (large gas cap) Pinda Natural depletion B Vermelha Water Injection Pinda Natural depletion C Pinda Natural depletion D Sendji Natural depletion E Sendji and Tachla Water and Gas injection F Sendji Natural depletion G Sendji Perpherial water injection H Sendji Natural depletion/water injection Field D: 8 wells plus 4 sidetrack Field H: 7 producers and 2 water injectors Field G: 52 wells plus 43 sidetrack and 8 water injectors Field F: 6 producer wells with ESP; 3 for the south and 3 for the North. Field E: 52 producers, 3 water injectors and 2 gas injectors also polymer injection for instance for increasing viscosity services 15

16 Characteristics and Analogies between Miocene Fields Reservoir: Lower and middle Miocene deep water turbidites channel complex sandstone with good petrophysical properties The sediment is mainly confined channel and weakly confined channel with fining upward trend. Channel complexes of 3-5 km wide and 800 to 1800 ft thickness. The good seismic quality helps to identify and characterize individual channels. Field NTG (%) Phi (%) Sw (%) K (md) API µ Angola A B C D E F Oildensity: mainly light oil and medium oil API differences: Biodegradation or Episodic filling by multiple hydrocarbon charges services 16

17 Development of Miocene Fields Drive mechanism: Water injection and WAG Fluid injection starts at start up or immedialetly after start up for pressure maintainance. Depending on proximity to gas export infrastructure, gas is dispiosed in to reservoir through WAG to avoid flaring. Field OOIP (MMBO) * Reserve (MMBO) URF % * Producer Injectors Reserve/well A B C D E F Water Injection WAG * OOIP also include undeveloped areas of the field which penalize URF. URF in developed channels sands is in theorderof40-50%. High recovery is driven by favorable rock and oil properties. Low Sorw and Sorg High KH and connectivity in main channel sands Medium to high API gravity Mobility ratio services 17

18 Project Objective Introduction Reservoir characteristics and depletion mechanisms: pre-salt (Early Cretaceous) fields, post-salt (Late Cretaceous) fields and post-salt (Miocene) fields Risks and uncertainties on reservoir performance Conclusions List of Content Congo & Angola Offshore-Congo River Basin Characteristics, exploitation approach and fields analogues services 18

19 Risks and uncertainities of Pre-salt fields Pre-salt lacustrine sandstone reservoir (Congo): OOIP Uncertainties: Loeme Salt: masks the seismic response Mainly related to structure and fluid contact depth and facies distribution Heterogeneity, permeability and connectivity Uncertainties in petrophisycal distribution leads a poor understanding of production performance/behaviour. Pre-salt lacustrine carbonate reservoir uncertanities (Angola): Difficult to predict reservoir quality based on depositional facies Limited distribution and connectivity of reservoir Complex mix of lithologies, and diagenetic history controls reservoir distribution services 19

20 Risks and uncertainties in Albian- Cenomanian Uncertainties related to volumes are: Quite heterogeneous reservoir both laterally and vertically (petrophysical parameters distribution). Reservoir fluid contacts due to distinct reservoir layers Uncertainties on Recovery are: Fault blocks are separated from the surrounding area and no water influx (salt tectonics) Weak aquifer and lateral facies heterogeneity. Non uniform aquifer and water injection movement (low Permeability layers) Fluid mobilities (permeablity and viscosity) Aquifer size and faults transmissibility uncertainties are critical parameters and due to complex structural setting it varies from field to field and analogue comparison can not be made Structures related to salt tectonics services 20

21 Risks and uncertainities in Miocene Field Uncertainty onooip: Fluid contacts depth Extent of channel Petrophysical properties (Net-to-gross, porosity and water saturation). During the field life a general reduction in OOIP value is observed. Oil recovery Uncertainties: Compartmentalization and fault sealing capacity Voidage replacement in block/zone basis Flow connectivity within and between channels Lateral continuity of channel sands Vertical transmissibility between individual overlaying channel sands. Aquifer presence and size Well Count uncertanities: reservoirs are less connected than predicted and additional wells were needed. Miocene field structural top Benguela-Belize Miocene CN6 Structure Top Zone 1 Benguela - Belize CN6 Miocene field fault Fault Transmissibilities (Incorporates transmissiblity Well, Seismic and SGR Data) Sealing Fault (Transmissibility: 0) Partial Seal (Transmissibility: 0.5) Non-Sealing Fault (Transmissibility: 1) services 21

22 List of Content Congo & Angola Offshore-Congo River Basin Characteristics, exploitation approach and fields analogues Project Objective Introduction Reservoir characteristics and depletion mechanisms: pre-salt (Early Cretaceous) fields, post-salt (Late Cretaceous) fields and post-salt (Miocene) fields Risks and uncertainties on reservoir performance Conclusions services 22

23 Conclusions (1/2) Based on the fields screened both in the northern and southern Congo basin the following conclusions were made. Pre-salt(Early Cretaceous) fields: A complex depositional and diagenesis history of pre-rift carbonate resulted a strong facies and reservoir quality variation. Therefore, predicting and making analogue comparison of non-marine carbonate reservoir distribution in Congo basin fields is difficult. Pre-salt fields in Northern Congo basin are mainly lacustrine turbiditic tight sandstone and its sedimentation was related to paleo geography and structural setting. Based on the data available, there is no HC field from an equivalent reservoir sequence in Southern Congo Basin to make analogue comparison with lacustrine sandstone. services 23

24 Conclusions (2/2) Albian-Cenomanian fields: A high range of petrophysical variation in Cenomanian-Albian reservoirs in Congo basin is due to alternating Transgression-progradation depositional system characterized by mixed carbonate-clastic deposits. Recovery Mechanisms for developed Albian and cenomenian fields are either by natural depletion or with water injection support and variation in recovery method and performances depends on field size, hydrocarbon fluid characteristics, average petrophysical properties and dynamic behavior of the reservoir. Miocene Fields: Miocene Reservoirs fields in southern Congo basin have comparable reservoir qualities,fluid properties and recovery factor, hence analogue comparison between different Miocene fields can be made. Miocene Fields in Congo basin fully developed by secondary recovery method via water injection and WAG from day one. Reservoir characteristics and performance behavior of southern Congo Miocene fields could be used as analogue for possible future Miocene explorative play in the Northern Congo basin. services 24

25 Acknowledgements I would thank Eni E&P Division Management for permission to present this work and related results and GAES colleagues for the technical support and needed assistance. services 25 San Donato Milanese October 2014

26 Thank you! services 26

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