MORE WELLS, MORE OIL—A CASE STUDY OF RESERVES GROWTH IN THE KENMORE FIELD

2006 ◽  
Vol 46 (1) ◽  
pp. 35
Author(s):  
J.E. Skinner ◽  
M.J. Altmann ◽  
T.H. Wadham
Keyword(s):  
Economic Value ◽  
Oil Field ◽  
Oil Fields ◽  
Seismic Survey ◽  
Current Estimate ◽  
Oil Reserves ◽  
Recoverable Reserves ◽  
Stock Tank ◽  
Infill Drilling

The Kenmore oil field in the Eromanga Basin of southwest Queensland was discovered in 1985. Since then, a further 32 wells have been drilled and more than 12.5 MMSTB of oil has been produced from the Birkhead Formation/Hutton Sandstone. Oil production over the last year has averaged 1,220 barrels per day totalling some 0.45 million stock tank barrels (MMSTB)Oil reserves in Kenmore were originally estimated at 2.2 MMSTB following the Kenmore–1 discovery well drilled in 1985. In the following 20 years, infill drilling, a 3D seismic survey, various reservoir studies and better -than-expected recovery efficiency, have steadily increased the ultimate recoverable reserves to the current estimate of 14.3 MMSTB.The growth of reserves at Kenmore is primarily attributed to better drainage of the complex reservoir framework within the lower Birkhead Formation resulting from recognition of the variable lateral connectivity of the reservoir. Due to the initial estimate of the ultimate field reserves being significantly smaller than now recognised and the resultant conservative drilling program, the economic value of the field was not maximised. This experience has implications for the ongoing development of the Kenmore field and suggests that other Birkhead/Hutton oil fields should be developed more aggressively to prevent history repeating itself.

Features and measures to improve the efficiency of development of a perspective small oil field

2020 ◽  
pp. 31-43
Author(s):  
T. K. Apasov ◽  
G. T. Apasov ◽  
E. E. Levitina ◽  
E. I. Mamchistova ◽  
N. V. Nazarova ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Oil Field ◽  
Oil Fields ◽  
Transport Infrastructure ◽  
Field Analysis ◽  
Field Development ◽  
Oil Reserves ◽  
Second Stage ◽  
Recoverable Reserves ◽  
Two Stages

Despite the current political and economic situation in Russia, mining in small oil fields is important and topical issue. We have conducted a geological and field analysis of the development of one of such small oil fields from setting into operation to shut down and have identified the reasons for the low production of oil reserves and the failure to achieve the design oil recovery factor. At the same time, the field has sufficient reserves of recoverable reserves, and there is an available transport infrastructure, which proves the necessity to consider rerun it for the development. For this purpose, geological and technical actions have been developed and are being proposed for implementation to improve the efficiency of field development. These actions envisage implementation in two stages: the first with minimal costs and the second with higher costs. At the first stage, at the existing reservoir pressure, we recommend to perform forced fluid withdrawals with an increase in depression on the reservoir. At the second stage, we offer actions at a higher cost, such as hydraulic fracturing, sidetracking. As a result of the analysis, actions have been developed to increase selection from initial recoverable reserves and increase the economic efficiency when the field is rerun.

DEVELOPMENT PLANNING FOR THE COSSACK AND WANAEA FIELDS

1994 ◽  
Vol 34 (1) ◽  
pp. 92
Author(s):  
G. B. Salter ◽  
W. P. Kerckhoff
Keyword(s):  
Cost Reduction ◽  
Water Injection ◽  
Development Planning ◽  
Oil Field ◽  
Oil Fields ◽  
Oil Reservoirs ◽  
Field Development ◽  
Oil Reserves ◽  
Oil Field Development ◽  
Significant Effort

Development of the Cossack and Wanaea oil fields is in progress with first oil scheduled for late 1995. Wanaea oil reserves are estimated in the order of 32 x 106m3 (200 MMstb) making this the largest oil field development currently underway in Australia.Development planning for these fields posed a unique set of challenges.Key subsurface uncertainties are the requirement for water injection (Wanaea only) and well numbers. Strategies for managing these uncertainties were studied and appropriate flexibility built-in to planned facilities.Alternative facility concepts including steel/concrete platforms and floating options were studied-the concept selected comprises subsea wells tied-back to production/storage/export facilities on an FPSO located over Wanaea.In view of the high proportion of costs associated with the subsea components, significant effort was focussed on flowline optimisation, simplification and cost reduction. These actions have led to potential major economic benefits.Gas utilisation options included reinjection into the oil reservoirs, export for re-injection into North Rankin or export to shore. The latter requires the installation of an LPG plant onshore and was selected as the simplest, safest and the most economically attractive method.

scholarly journals Two-Stage Geothermal Well Clustering for Oil-to-Water Conversion on Mature Oil Fields

Geosciences ◽  
2021 ◽  
Vol 11 (11) ◽  
pp. 470
Author(s):  
Josipa Hranić ◽  
Sara Raos ◽  
Eric Leoutre ◽  
Ivan Rajšl
Keyword(s):  
Spatial Arrangement ◽  
Oil Wells ◽  
Oil Field ◽  
Oil Fields ◽  
Two Stage ◽  
Oil Companies ◽  
Geothermal Potential ◽  
Clustering Approach ◽  
Water Cut

There are numerous oil fields that are approaching the end of their lifetime and that have great geothermal potential considering temperature and water cut. On the other hand, the oil industry is facing challenges due to increasingly stringent environmental regulations. An example of this is the case of France where oil extraction will be forbidden starting from the year 2035. Therefore, some oil companies are considering switching from the oil business to investing in geothermal projects conducted on existing oil wells. The proposed methodology and developed conversions present the evaluation of existing geothermal potentials for each oil field in terms of water temperature and flow rate. An additional important aspect is also the spatial distribution of existing oil wells related to the specific oil field. This paper proposes a two-stage clustering approach for grouping similar wells in terms of their temperature properties. Once grouped on a temperature basis, these clusters should be clustered once more with respect to their spatial arrangement in order to optimize the location of production facilities. The outputs regarding production quantities and economic and environmental aspects will provide insight into the optimal scenario for oil-to-water conversion. The scenarios differ in terms of produced energy and technology used. A case study has been developed where the comparison of overall fields and clustered fields is shown, together with the formed scenarios that can further determine the possible conversion of petroleum assets to a geothermal assets.

scholarly journals OIL SPILL PREVENTION AND TREATMENT IN OFFSHORE OIL INDUSTRY OF CHINA

1989 ◽  
Vol 1989 (1) ◽  
pp. 235-238
Author(s):  
Lu Mu-Zhen
Keyword(s):  
Oil Spill ◽  
Joint Venture ◽  
Oil And Gas ◽  
Oil Field ◽  
Oil Fields ◽  
Seismic Survey ◽  
Oil Exploration ◽  
Foreign Companies ◽  
Offshore Oil ◽  
Laws And Regulations

ABSTRACT The China National Offshore Oil Corporation (CNOOC), established in October 1982, is the sole Chinese company dealing with offshore oil exploration, development, and production. It has four regional corporations, and four specialized corporations, as well as seventeen joint venture corporations. CNOOC has four representative offices outside China. Since the Sino-foreign cooperation for offshore oil exploration and development in China started, 360,000 line km of seismic survey have been shot, thirty-nine oil and gas bearing structures have been found, fifteen oil fields have been evaluated as having large hydrocarbon accumulations, nine oil fields have been developed and put into production, 179 exploratory wells have been drilled, and CNOOC has signed thirty-nine contracts with a total of forty-five foreign companies from twelve countries. There are five laws and regulations in the PRC affecting offshore oil development and marine environmental pollution. In accord with these laws and regulations, CNOOC has reviewed four environmental impact statements for offshore oil fields received from its regional corporations. CNOOC has made oil spill contingency plans for the Cheng-Bei offshore oil field in Bo-Hai, and the Wei 10-3 offshore oil field in the Gulf of Bei-Bu. Some oil spill combating equipment is owned by the Bo-Hai Oil Corporation and the Nan-Hai West Oil Corporation, selected on the basis of the crude oil characteristics.

Seismic modelling and its application on designing the seismic survey parameters, a case study of an Iranian oil field

2019 ◽  
Vol 50 (1) ◽  
pp. 75-85
Author(s):  
Sadegh Saffarzadeh ◽  
Abdolrahim Javaherian ◽  
Hossein Hasani ◽  
Maryam Sadri
Keyword(s):  
Oil Field ◽  
Seismic Survey ◽  
Seismic Modelling

scholarly journals Quantification of recoverable oil reserves in the S6, S7 and S8 sands, in the Sigmoilina zone, at the Jusepin field in the Orinoco oil and gas basin, Venezuela

2021 ◽  
Vol 1 ◽  
pp. 33-38
Author(s):  
Adrián José RODRIGUEZ LINARES ◽  
◽  
Elena Viktorovna KARELINA ◽  
Keyword(s):  
Oil And Gas ◽  
Oil Industry ◽  
Oil Fields ◽  
Oil Reserves ◽  
Recoverable Reserves ◽  
Form Part ◽  
Production History ◽  
Oil Deposits ◽  
Original Oil In Place ◽  
Popular Power

Relevance of the work. Quantifying these oil reserves allows Venezuela to lead the ranking as the country with the largest oil reserves worldwide Purpose of the work. Is related to the need of quantification in the recoverable oil reserves in the field of Husepin (Monagas state, Venezuela) for the oil industry. The methodology of the research. The La Pica 01 Field is made up of 509 wells, of which 49 wells were used to elaborate the correlations, since they have spontaneous potential and resistivity curves. For each well, the tops and bases of the units were determined by analyzing the behavior of the electrical responses of each of the sands, applying the basic concepts of stratigraphy, as well as a detailed compilation of all the information that corresponds to the wells that form part of the study to obtain a standard record that contains all the favorable data and be able to carry out the correlations. Research results. In the S6 sand, 4 oil deposits were found and an Original Oil In Place of 15,875.32 thousands of normal barrels and recoverable reserves of 2,857. 5576 thousands of normal barrels were estimated. For S8 sand, 5 oil fields were defined and an Original Oil In Place of 25,940.86 thousands of normal barrels and recoverable reserves of 4,669. 3548 thousands of normal barrels were estimated. Original Oil In Place was not calculated in the S7 sand because it has no deposits. Recommendations. Review the production history and verify which wells can be re-incorporated into an oil extraction plan and Submit the reserves of the study fields to the Ministry of Popular Power for Energy and Petroleum (MENPET) taking into account the results obtained in this investigation. Conclusions. 4 oil deposits were found in the S6 sand and 5 oil deposits were found in the S8 sand and each of them were with stratigraphic limits, structural limits and fluid contact. No oil deposits were found in the S7 sand, although records have been taken in the northwest of the field show thicknesses of ANP at this stratigraphic level. Keywords: oil reserves, Orinoco basin, Sigmoilina zone, well, deposit.

DISCOVERY OF THE WANAEA AND COSSACK OIL FIELDS

1991 ◽  
Vol 31 (1) ◽  
pp. 22
Author(s):  
A.N. Bint
Keyword(s):  
Upper Jurassic ◽  
Oil Field ◽  
Oil Fields ◽  
Seismic Survey ◽  
Gas Oil ◽  
Water Contact ◽  
North West ◽  
The North ◽  
Reservoir Development ◽  
Oil Water

Exploration of the Dampier Sub-basin on the North West Shelf of Australia commenced with a reconnaissance seismic survey in 1965. In 1969 Madeleine-1, the first well drilled on the Madeleine Trend, encountered water bearing Upper Jurassic sandstones. Following acquisition of a regional grid of modern seismic in 1985 and 1986, and comprehensive hydrocarbon habitat studies, the Wanaea and Cossack prospects were matured updip from Madeleine 1. They were proposed to have improved reservoir development and an oil charge.The Wanaea Oil Field was discovered in 1989 when Wanaea-1 encountered a gross oil column of 103 m in the Upper Jurassic Angel Formation. The well flowed 49° API oil at 5856 BPD (931 kL/d) with a gas-oil ratio of 1036 SCF/STB. Two appraisal wells were drilled in the field in 1990.The Cossack Oil Field was discovered in 1990 when Cossack-1 encountered a gross oil column of 54 m also in the Angel Formation. The oil-water contact is 18 m deeper than in Wanaea-1. Cossack-1 flowed 49° API oil at 7200 BPD (1145 kL/d) with a gas-oil ratio of 98 SCF/STB.The Angel Formation reservoir consists of mass flow sandstones interbedded with bioturbated siltstones. Sandstone porosities average 16 to 17 per cent for both the Wanaea and Cossack Fields. Permeabilities average about 300 mD at Wanaea and about 500 mD at Cossack.An extensive 3-D seismic survey was conducted over the Wanaea and Cossack Fields in 1990. Final reserves calculations await interpretation of this survey, but it is clear that the combined Wanaea and Cossack oil reserve is the largest outside Bass Strait.

Economic Transportation Risk Assessment From Offshore Oil Fields to Refineries

2002 ◽  
Author(s):  
Renato F. Mendes ◽  
Kleber J. A. Porto Silva ◽  
Luiz Fernando S. Oliveira
Keyword(s):  
Oil Field ◽  
Oil Fields ◽  
Pipeline System ◽  
Financial Assessment ◽  
Transportation Risk ◽  
Comparative Risk ◽  
Offshore Oil ◽  
Transportation Route ◽  
Business Interruption

This paper describes an analysis of the transportation reliability and economic risk associated with potential accidents during the lifetime of a brand new enterprise. The methodology was applied during the technical-financial assessment of offshore and onshore transportation from oil fields to refineries. It considered operations involving the potential for environment damage and business interruption. The case study considered two major configurations: Maritime+Pipelines: combining FPSOs (Floating Production, Storage and Offloading), tankers, terminals, and onshore pipelines; and Pure Pipelines: SSs (Semi-submersibles) and offshore and onshore pipeline system conveying oil to refineries. Each installation/activity with potential to generate an accident was represented by one block on the diagram, in the reliability study. The consequences to the transportation enterprise were defined based on economic impact. It was necessary to mine information on the environmental costs of past accidents within the company, as well as worldwide. Business interruption was considered for the transportation project and also for the refineries connected in the process. The risk for each route configuration from oil field to refinery was developed by plotting the frequency and consequence data in a spreadsheet for each activity along the transportation route. As a result we developed a comparative risk analysis table to support a major financial assessment. Beyond the traditional process of assessing projects in terms of investment and return, PETROBRAS is now considering other aspects, such as potential accidents that may play a role in assessing financial feasibility.

scholarly journals Oil initially in place calculation by geologic and dynamic methods in Nahr Umar formation of Nasiriya oil field

2020 ◽  
Vol 10 (3) ◽  
pp. 1-20
Author(s):  
Ahmed A. Suhail ◽  
Fadhil S. Kadhim ◽  
Mohammed H. Hafiz
Keyword(s):  
Reservoir Management ◽  
Static Model ◽  
Economic Advantage ◽  
Oil Field ◽  
Southern Region ◽  
Oil Fields ◽  
Petrophysical Properties ◽  
Oil Reserves ◽  
Dynamic Methods ◽  
Original Oil In Place

Original oil in place is most critical stages of reservoir management, where the economic advantage of the reservoir is evaluated by estimation of the petrophysical properties and oil reserves. This work was carried out in five wells of Nasiriya oilfield, which is one of the Iraqi oil fields in the southern region. The aim of this study is to calculate oil in place from available data in Nahr Umar formation, having a complex lithology by two methods (static and simulation). It was found that the static model used for computing the petrophysical distribution oil in place was equal to (114  MM or 716 MM STB) and 117 MM  or 734 MM STB for the dynamic one

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