Rethinking Conventional Field Development: 3D Shows Direct Detection of Bypassed Oil Reserves

1994 ◽  
Author(s):  
D.M. Sibley ◽  
S.S. Mastoris
Keyword(s):  
Direct Detection ◽  
Field Development ◽  
Oil Reserves ◽  
Bypassed Oil ◽  
Conventional Field

Oil Reserves Evaluation and Field Development plan of Hakim Oil Field in Libya

2016 ◽  
Vol 18 (1) ◽  
pp. 39-53
Author(s):  
Omar Salih ◽  
Mahmoud Tantawy ◽  
Sayed Elayouty ◽  
Atef Abd Hady
Keyword(s):  
Oil Field ◽  
Development Plan ◽  
Field Development ◽  
Oil Reserves

Development of efficiency increase methods for water injection

2020 ◽  
pp. 57-60
Author(s):  
K.I. Mustafaev ◽  
◽  
◽  
Keyword(s):  
Water Injection ◽  
Cost Effective ◽  
Current Interest ◽  
Residual Oil ◽  
Production Well ◽  
Field Development ◽  
Oil Reserves ◽  
Production Wells ◽  
Efficiency Increase

The production of residual oil reserves in the fields being in a long-term exploitation is of current interest. The extraction of residual oil in such fields was cost-effective and simple technological process and is always hot topic for researchers. Oil wells become flooded in the course of time. The appearance of water shows in production wells in the field development and operation is basically negative occurrence and requires severe control. Namely for this reason, the studies were oriented, foremost, to the prevention of water shows in production well and the elimination of its complications as well. The paper discusses the ways of reflux efficiency increase during long-term exploitation and at the final stages of development to prevent the irrigation and water use in production wells.

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 Limitation of gas inflows under the conditions of development of Botuobinsky horizon

2020 ◽  
pp. 159-166
Author(s):  
I. I. Krasnov ◽  
V. F. Tomskaya ◽  
E. I. Inyakina ◽  
K. O. Tomsky ◽  
M. S. Ivanova ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Geological Structure ◽  
Operating Conditions ◽  
Computational Method ◽  
Field Development ◽  
Oil Reserves ◽  
Main Factors ◽  
The Republic ◽  
Effective Development ◽  
Oil Rim

The article presents the results of the study of the geological structure of oil and gas deposits in Botuobinsky horizon, affecting the gasification of producing wells and gas breakthrough into the oil rim in the conditions of field development. In the course of the research, a characteristic of the reservoir was given, and the optimal gas-free flow rate was determined by a computational method, which allows us to limit the gas inflow for the operating conditions of the Srednebotuobinskoye oil and gas condensate field. The field under consideration is one of the unique storehouses of the East-Siberian oil cluster located in the Republic of Sakha (Yakutia). The main factors influencing the effective development of oil reserves of gas and oil deposits within the Central block and the Kurung license area are substantiated.

THE TARBAT-IPUNDU OIL FIELD, A CASE STUDY IN IDENTIFYING BYPASSED OIL

1998 ◽  
Vol 38 (1) ◽  
pp. 36
Author(s):  
T.P. Lonergan ◽  
P.G. Ryles ◽  
S.T. McClure ◽  
D.W. McMillan
Keyword(s):  
Multidisciplinary Team ◽  
Development Program ◽  
Oil Field ◽  
Growth Potential ◽  
Total Production ◽  
Field Development ◽  
The North ◽  
Bypassed Oil ◽  
Existing Data ◽  
Eromanga Basin

Since 1995 the Tarbat-Ipundu Field has developed from a marginal 200 BOPD (31.8 kL/d) field with perceived limited growth potential to a developing resource with production up to 3,000 BOPD (476.9 kL/d). This increase was achieved through the efforts of a dedicated multidisciplinary team and an aggressive 'fit for purpose' drilling and evaluation program.The Tarbat-Ipundu Field is located in PL 52 of ATP 299P in southwestern Queensland, approximately 115 km to the northeast of the Jackson Oil Field. The field was discovered by Hartogen Energy Ltd in 1986 with the drilling of Ipundu 1 which came on-line at 100 BOPD (15.9 kL/d) from the Wyandra Sandstone and the Murta Member. The discovery well was followed by the drilling of Tarbat-1 in 1988 on a subculmination to the north. Tarbat-1 encountered oil in the Wyandra Sandstone but watered out after producing 17 KSTB (2,702 kL) of oil. During 1991 a further four wells were drilled in the Ipundu Field by the then operator, Ampolex Pty Ltd. Two of these wells were plugged and abandoned. In January 1994 the field was producing at 220 BOPD (34.9 kL/d) after a total production of 350 KSTB.The Santos Group acquired a majority interest and Operatorship of the Tarbat-Ipundu Field in 1994. An integrated geological and engineering evaluation of Tarbat-1, incorporating experience gained in other parts of the Eromanga Basin, indicated the potential for bypassed oil in the Hutton Sandstone. Similarly, additional potential was recognised in the Wyandra Sandstone and Murta Member in the Tarbat-Ipundu wells. To evaluate this potential Tarbat-2 was drilled in August 1995 at a location 315 m to the northwest of Tarbat-1. Drill stem tests in Tarbat-2 resulted in flows of 2,037 BOPD (323.8 kL/d) from a 26 m gross hydrocarbon column in the Hutton Sandstone and 770 BOPD (122.4 kL/d) from a 14 m gross hydrocarbon column in the Wyandra Sandstone.An aggressive appraisal and development program followed the drilling of Tarbat-2 which has resulted in the drilling of an additional 25 wells. Proved and Probable Oil in Place estimates have increased from 5.2 MMSTB (0.826 ML) in 1994 to 44.2 MMSTB (7.02 ML) in 1997. As at June 1997 the field produces oil from the WyandraSandstone, Murta Member and Hutton Sandstone of the Eromanga Basin. A combined oil offtake of up to 3,000 BOPD (476.9 kL/d) has been achieved from the field. Continued field development is planned for 1998.The successful 're-discovery' of the Tarbat-Ipundu Field illustrates the potential benefit of a systematic review and integration of all existing data via a multidisciplinary team. The increasing cost of new data acquisition makes it imperative that the existing data is thoroughly evaluated prior to the investment of further exploration capital. The Tarbat-Ipundu Field demonstrates the potential to add significant new reserves from focussed targeting and evaluation of potential bypassed hydrocarbon accumulations.

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.

Estimating recoverable oil reserves using integral displacement characteristics based on probabilistic methodology

2021 ◽  
pp. 78-88
Author(s):  
V. S. Shumko ◽  
E. I. Mamchistova ◽  
S. S. Kuzovlev
Keyword(s):  
Comparative Analysis ◽  
Probabilistic Method ◽  
Hydrodynamic Modeling ◽  
Computational Time ◽  
Actual Problem ◽  
Field Development ◽  
Oil Reserves ◽  
Oil Displacement ◽  
Filtration Properties ◽  
Require Information

Estimation of recoverable oil reserves is an actual problem in field development. One way to estimate reserves is to use the characteristics of oil displacement by water. This method, in contrast to hydrodynamic modeling, doesn't take a long computational time and doesn't require information on the geological and filtration properties of the objects under consideration.The article discusses the use of integral displacement characteristics based on a probabilistic method for assessing potentially recoverable oil reserves. We describe an algorithm for estimating reserves by this method. In the course of the comparative analysis, the efficiency of the method was demonstrated depending on the watercut at the end of the approximation interval. As a result, with a watercut of less than 90 %, a better forecast was found than in the classical application of the characteristics of oil displacement by water.

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