RESERVOIR CHARACTERISATION OF THE TOOLACHEE UNIT 'C' IN THE MOOMBA/BIG LAKE AREA: FOCUSSING ON MINIMISING RISK

1995 ◽  
Vol 35 (1) ◽  
pp. 92
Author(s):  
S.l. Mackie ◽  
C.A. Grasso ◽  
S.R. McGuire
Keyword(s):  
Field Performance ◽  
Depositional Environments ◽  
Oil Field ◽  
Lake Area ◽  
Reservoir Model ◽  
Attribute Analysis ◽  
Net To Gross ◽  
Gippsland Basin ◽  
First Time ◽  
3D Seismic Data

Mackerel, the third largest oil field in the Gippsland Basin, is a mature field with over 80 per cent of reserves produced from 18 original development wells.The initial Mackerel development was based on a fairly simplistic reservoir model incorporating the results of the four exploration wells. The net to gross was anticipated at 90 per cent throughout the reservoir and no significant permeability barriers were expected. After 10 years of production a review of field performance indicated the reservoir was not as homogenous as first anticipated.Redevelopment of the Mackerel Field began in 1990 following the acquisition of the first of two high resolution 3D surveys and culminated in the drilling of 18 additional wells from the Mackerel platform during 1993 and 1994. It was these 3D surveys which changed the entire reservoir model of Mackerel to one of a far more compartmentalised nature.Seismic attribute analysis, when calibrated to 2D forward modelling was used to predict intra-reser- voir seals and the distribution of poorer quality reservoir; both not previously recognised over the field. The truncation points of the intra-reservoir seals against the main field-wide trapping unconformity were accurately mapped using seismic attributes and image enhancement techniques such as ER Mapper. Previously undetectable fault extensions, with throw around 10 m, can act as partial flow barriers and were recognised for the first time via 'sun-angle illumination' of azimuth maps. This allowed optimum well placement and helped explain historical field performance. Horizon slicing techniques and the calibration of volume attributes were used to establish depositional environments and seal capacity of the predicted intra-reservoir seals.The drilling results have shown that over the production life of the Mackerel Field the reservoir consists of a number of drainage compartments, each separated by seismically resolvable intra-res- ervoir seals.The redevelopment of the Mackerel field increased production rate by 18 thousand barrels per day (kBD) in 1993, and proved additional capture reserves of which approximately 40 percent can be directly attributed to the 3D seismic data and the applied interpretation techniques.

GEOPHYSICAL OPTIMISATION OF THE MACKEREL FIELD RE-DEVELOPMENT—GIPPSLAND BASIN, AUSTRALIA

1995 ◽  
Vol 35 (1) ◽  
pp. 79
Author(s):  
M.G. Cousins
Keyword(s):  
Field Performance ◽  
Depositional Environments ◽  
Oil Field ◽  
Reservoir Model ◽  
Well Placement ◽  
Attribute Analysis ◽  
Net To Gross ◽  
Gippsland Basin ◽  
First Time ◽  
3D Seismic Data

Mackerel, the third largest oil field in the Gippsland Basin, is a mature field with over 80 per cent of reserves produced from 18 original development wells.The initial Mackerel development was based on a fairly simplistic reservoir model incorporating the results of the four exploration wells. The net to gross was anticipated at 90 per cent throughout the reservoir and no significant permeability barriers were expected. After 10 years of production a review of field performance indicated the reservoir was not as homogenous as first anticipated.Redevelopment of the Mackerel Field began in 1990 following the acquisition of the first of two high resolution 3D surveys and culminated in the drilling of 18 additional wells from the Mackerel platform during 1993 and 1994. It was these 3D surveys which changed the entire reservoir model of Mackerel to one of a far more compartmentalised nature.Seismic attribute analysis, when calibrated to 2D forward modelling was used to predict intra-reservoir seals and the distribution of poorer quality reservoir; both not previously recognised over the field. The truncation points of the intra-reservoir seals against the main field-wide trapping unconformity were accurately mapped using seismic attributes and image enhancement techniques such as ER Mapper. Previously undetectable fault extensions, with throw around 10 m, can act as partial flow barriers and were recognised for the first time via 'sun-angle illumination' of azimuth maps. This allowed optimum well placement and helped explain historical field performance. Horizon slicing techniques and the calibration of volume attributes were used to establish depositional environments and seal capacity of the predicted intra-reservoir seals.The drilling results have shown that over the production life of the Mackerel Field the reservoir consists of a number of drainage compartments, each separated by seismically resolvable intra-reservoir seals.The redevelopment of the Mackerel field increased production rate by 18 thousand barrels per day (kBD) in 1993, and proved additional capture reserves of which approximately 40 percent can be directly attributed to the 3D seismic data and the applied interpretation techniques.

THE INTEGRATION OF MODERN TECHNOLOGY IN GIPPSLAND'S CENTRAL FIELDS STUDY

1994 ◽  
Vol 34 (1) ◽  
pp. 513
Author(s):  
P.V.Hinton P.V.Hinton ◽  
M.G.Cousins ◽  
P.E.Symes
Keyword(s):  
Seismic Data ◽  
Field Performance ◽  
Simulation Models ◽  
Modern Technology ◽  
Depositional Environments ◽  
Seismic Attribute ◽  
Sequence Stratigraphic ◽  
Multidisciplinary Study ◽  
Attribute Analysis ◽  
Definition Of

The central fields area of the Gippsland Basin, Australia, includes the Halibut, Cobia, Fortescue, and Mackerel oil fields. These large fields are mature with about 80% of the reserves produced. During 1991 and 1992 a multidisciplinary study, integrating the latest technology, was completed to help optimise the depletion of the remaining significant reserves.A grid of 4500 km of high resolution 3D seismic data covering 191 square kilometres allowed the identification of subtle structural traps as well as better definition of sandstone truncation edges which represent the ultimate drainage points. In addition, the latest techniques in seismic attribute analysis provided insight into depositional environments, seal potential and facies distribution. Sequence stratigraphic concepts were used in combination with seismic data to build complex multi million cell 3D geological models. Reservoir simulation models were then constructed to history match past production and to predict future field performance. Facility studies were also undertaken to optimise depletion strategies.The Central Fields Depletion Study has resulted in recommendations to further develop the fields with about 80 work-overs, 50 infill wells, reduction in separator pressures, and gas lift and water handling facility upgrades. These activities are expected to increase ultimate reserves and production. Some of the recommendations have been implemented with initial results of additional drilling on Mackerel increasing platform production from 22,000 BOPD to over 50,000 BOPD. An ongoing program of additional drilling from the four platforms is expected to continue for several years.

Seismic Stratigraphy and Seismic Geomorphology: Insights on Characterization of a Carbonate Reservoir

2011 ◽  
Vol 138-139 ◽  
pp. 447-452 ◽  
Author(s):  
Ru Tai Duan ◽  
Zhen Kui Jin ◽  
Chong Hui Suo
Keyword(s):  
Seismic Data ◽  
Seismic Stratigraphy ◽  
Depositional Environments ◽  
Carbonate Reservoir ◽  
Oil Field ◽  
3D Seismic ◽  
Element Analysis ◽  
Hydrocarbon Production ◽  
Seismic Geomorphology ◽  
3D Seismic Data

Seismic stratigraphy and seismic geomorphology provides an indication of a carbonate platform’s internal and external architecture. High quality 3D seismic data integrated with wireline logs and core materials furthers detailed depositional element analysis, lithology prediction and diagenetic modification of the stratigraphic section, which help to build a depositional model, sequence stratigraphy framework and enhance the evaluation of the reservoir potential of this unit and a prediction of fluid flow during hydrocarbon production. This study mainly focus on using 3D seismic data calibrated with core and logs from oil field A to characterize the stratigraphy and geomorphology of the depositional elements of the carbonate reservoir (Aptaian Stage) and infer the process of the deposition where appropriate. Integration of seismic data with well data provides the frame work for reconstruction depositional evolution history the reservoir. The high seismic resolution of the A reservoirs also provides useful analogs for other subsurface reservoirs from similar depositional environments.

Technology, investment and people: a process for extending the life of the Central Fields Complex, Gippsland Basin

2008 ◽  
Vol 48 (1) ◽  
pp. 133
Author(s):  
Michael Gross ◽  
Abdul Aziz Abdul Rahim ◽  
Erin Broad ◽  
Dean Grant ◽  
Brad Hargreaves
Keyword(s):  
Data Integration ◽  
Data Quality ◽  
Seismic Data ◽  
Depositional Environments ◽  
3D Seismic ◽  
Initial Development ◽  
Technology Investment ◽  
Technical Advances ◽  
Gippsland Basin ◽  
3D Seismic Data

The greater Central Fields complex of the Gippsland Basin, comprised of the Halibut, Fortescue and Mackerel fields, has produced 1.7 billion barrels of oil from four platforms in 37 years of production. After the initial development drilling phases from Halibut (1969–70), Mackerel (1977–80), Fortescue (1983–86) and Cobia (1983–85) platforms and five in-fill drilling campaigns (1992–2003) it is still possible to target unswept highly productive multi-darcy reservoirs along with bypassed zones in lower quality sands. During 2007, a six well program was completed from the Halibut platform using an upgraded workover rig that added significant volumes with combined initial rates of more than 16,000 barrels of oil per day. In addition, despite being conductor limited, the program tested strategic concepts and demonstrated significant remaining potential in a variety of reservoir qualities and depositional environments. The outstanding success of the 2007 program was based on an up-to-date geologic framework, key technical advances, ongoing investment commitment and multi-discipline integration across workplace functions. Advancements in 3D seismic data quality and analyses, reservoir surveillance, innovative slot recovery and data integration all played a role in the success of the program. Building on the success elements of the 2007 program, a higher capacity rig has been mobilised and upgraded to apply new drilling technologies to access the remaining potential and help mitigate basin decline.

scholarly journals Petroleum potential of Tyumen suite within Imilorsko-Istochny subsoil area

2019 ◽  
pp. 23-29
Author(s):  
V. V. Mezhetsky ◽  
R. N. Khasanov ◽  
E. S. Taracheva ◽  
A. D. Malyugina
Keyword(s):  
Seismic Data ◽  
Wave Pattern ◽  
Geological Structure ◽  
Oil Field ◽  
Joint Analysis ◽  
Petroleum Potential ◽  
Attribute Analysis ◽  
Bed Thickness ◽  
And Behavior ◽  
3D Seismic Data

The article analyzes features of the geological structure of Tyumen suite (J2 layer of the Imilorskoye oil field) based on detailed analysis of 3D seismic data, including maps of spectral decomposition, attribute analysis, and behavior of the wave pattern. A joint analysis of morphology presented maps can be as a basis for paleosedimentation reconstruction and prediction for distribution zones of effective bed thickness.  

Uncertainty Analysis of a Giant Oil Field in the Middle East Using Surrogate Reservoir Model

2006 ◽  
Author(s):  
Shahab D. Mohaghegh ◽  
Hafez H. Hafez ◽  
Razi Gaskari ◽  
Masoud Haajizadeh ◽  
Maher Kenawy
Keyword(s):  
Middle East ◽  
Uncertainty Analysis ◽  
Oil Field ◽  
Reservoir Model

ISOTOPE-GEOCHEMICAL FEATURES OF AUTHENIC CARBONATES OF THE YU1 PRODUCING HORIZON OF THE VERKH-TARSKOYE OIL FIELD (SOUTH OF WESTERN SIBERIA)

2020 ◽  
pp. 20-28
Author(s):  
L. G. Vakulenko ◽  
◽  
O. D. Nikolenko ◽  
D. A. Novikov ◽  
P. A. Yan ◽  
...  
Keyword(s):  
Isotopic Composition ◽  
Carbonate Rocks ◽  
Western Siberia ◽  
Oil Field ◽  
Third Generation ◽  
The Third ◽  
First Time ◽  
Different Sources ◽  
Sources Of Co2 ◽  
Comprehensive Study

A comprehensive study of the composition of sand and silt deposits of the Yu1 horizon of the Vasyuganskaya Formation upper part of the Verkh-Tarskoye oil field has been carried out. Associations of authigenic minerals have been determined in their cement, among which the calcite is the most widespread. According to petrographic parameters, three generations of calcite have been identified for which detailed isotopicgeochemical and ultramicroscopic studies were carried out for the first time. Wide and multi directional changes in the isotopic composition of carbon and oxygen and in the chemical composition of carbonate minerals were recorded, they indicate significant variations in the conditions of diagenesis and catagenesis, primarily temperature, and different sources of CO2. Significant variations in the isotopic composition of formation waters and its relationship with the isotopic composition of carbonates have been established. Thus, a narrow interval of close δ13C values was revealed, amounting to –10.5 to –9.1 ‰ in the formation waters of group II, and from –10.7 to –9.1 ‰ in calcites of the third generation. The source of CO2 in this system should be considered a carbon dioxide, which is formed in the process of metamorphism of carbonate rocks of the Paleozoic age.

A Success Story in Managing and Optimising Gas Lift Wells in Matured Oil Field: Automated Workflows in Digital Fields as Enablers to Accelerate Opportunities Creation and Production Optimisation

2021 ◽  
Author(s):  
Amir Badzly M. Nazri ◽  
W. M. Anas W. Khairul Anuar ◽  
Lucas Ignatius Avianto Nasution ◽  
Hayati Turiman ◽  
Shar Kawi Hazim Shafie ◽  
...  
Keyword(s):  
Model Validation ◽  
Field Performance ◽  
Oil Field ◽  
Working Environment ◽  
Key Factors ◽  
Collaborative Working ◽  
Water Cut ◽  
Integrated Operations ◽  
Collaborative Working Environment ◽  
Gas Lift

Abstract Field S located in offshore Malaysia had been producing for more than 30 years with nearly 90% of current active strings dependent on gas lift assistance. Subsurface challenges encountered in this matured field such as management of increasing water-cut, sand production, and depleting reservoir pressure are one of key factors that drive the asset team to continuously monitor the performance of gaslifted wells to ensure better control of production thereby meeting target deliverability of the field. Hence, Gas Lift Optimization (GLOP) campaign was embarked in Field S to accelerate short term production with integration of Gas Lift Management Modules in Integrated Operations (IO). A workflow was created to navigate asset team in this campaign from performing gaslift health check, diagnostic and troubleshooting to data and model validation until execution prior to identification of GLOP candidates with facilitation from digital workflows. Digital Fields and Integrated Operations (IO) developed in Field S provided an efficient collaborative working environment to monitor field performance real time and optimize production continuously. Digital Fields comprises of multiple engineering workflows developed and operationalized to act as enablers for the asset team to quickly identify the low-hanging fruit opportunities. This paper will focus on entire cycle process of digital workflows with engineer's intervention in data hygiene and model validation, the challenges to implement GLOP, and results from the campaign in Field S.

scholarly journals Stratigraphy and Depositional Environment of Mauddud Formation in Ratawi Oil wells of Southern Iraq

2021 ◽  
Vol 877 (1) ◽  
pp. 012030
Author(s):  
Maha Razaq Manhi ◽  
Hamid Ali Ahmed Alsultani
Keyword(s):  
Deep Sea ◽  
Lower Cretaceous ◽  
Depositional Environment ◽  
Carbonate Platform ◽  
Depositional Environments ◽  
Oil Wells ◽  
Oil Field ◽  
Microfacies Analysis ◽  
Thin Sections ◽  
Southern Iraq

Abstract The Mauddud Formation is Iraq’s most significant and widely distributed Lower Cretaceous formation. This Formation has been investigated at a well-23 and a well-6 within Ratawi oil field southern Iraq. In this work, 75 thin sections were produced and examined. The Mauddud Formation was deposited in a variety of environments within the carbonate platform. According to microfacies analysis studying of the Mauddud Formation contains of twelve microfacies, this microfacies Mudstone to wackestone microfacies, bioclastic mudstone to wackestone microfacies, Miliolids wackestone microfacies,Orbitolina wackestone microfacies, Bioclastic wackestone microfacies, Orbitolina packstone microfacies, Peloidal packstone microfacies, Bioclastic packstone microfacies, Peloidal to Bioclastic packstone microfacies, Bioclastic grainstone microfacies, Peloidal grainstone microfacies, Rudstone microfacies. Deep sea, Shallow open marine, Restricted, Rudist Biostrome, Mid – Ramp, and Shoals are the six depositional environments in the Mauddud Formation based on these microfacies.

Sign in / Sign up

Export Citation Format

Share Document