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

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.

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.

scholarly journals 3D Geological Modeling for Yamama Reservoir in Subba, Luhias and Ratawi Oil Fields, South of Iraq

2019 ◽  
Vol 60 (5) ◽  
pp. 1023-1036
Author(s):  
Naseem Sh. ALhakeem ◽  
Medhat E. Nasser ◽  
Ghazi H. AL-Sharaa
Keyword(s):  
Water Saturation ◽  
Salt Water ◽  
Oil Field ◽  
Oil Fields ◽  
Geological Model ◽  
Petrophysical Properties ◽  
Geological Modeling ◽  
3D Geological Modeling ◽  
South Of Iraq ◽  
Resistivity Log

3D geological model for each reservoir unit comprising the Yamama Formation revealed to that the formation is composed of alternating reservoirs and barriers. In Subba and Luhais fields the formation began with barrier YB-1 and four more barriers (YB-2, YB-3, YB-4, YB-5), separated five reservoirs (YR-A, YR-B, YR-C, YR-D, YR-E) ranging in thickness from 70 to 80 m for each of them deposited by five sedimentary cycles. In the Ratawi field the formation was divided into three reservoir units (YR-A, YR-B, and YR-C) separated by two barrier units (YB-2 and YB-3), the first cycle is missing in Ratawi field.   The study involves 1 well in Luhais field (Lu-12), 3 wells in Subba field (Su-7, Su-8, and Su-9), and 5 wells in Ratawi field (Rt-3, Rt-4, Rt-5, Rt-6 and Rt-7), the Luhais, Subba, and Ratawi fields located in the Mesopotamia zone (Zubair subzone). The reservoir units (YR-C and YR-D) in Subba oil field, and YR-B in Ratawi oil field represent the major reservoir units that characterized by the best Petrophysical properties (the highest porosity, the lowest water saturation, and the best Net Pay Thickness), Luhais oil field has poor to moderate Petrophysical properties and low oil bearing in YR-A, YR-B and YR-C units, and produce heavy oil and salt water from YR-D and YR-E as indicated by low resistivity log reading, and according to the Drill Steam Test (DST) with the description of cutting in final geological reports.

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.

scholarly journals Geological Model for Khasib Formation of East Baghdad Field Southern Area

2020 ◽  
Vol 10 (3) ◽  
pp. 21-35
Author(s):  
Layth A. Jameel ◽  
Fadhil S. Kadhim ◽  
Hussein Ilaibi Al-Sudani
Keyword(s):  
Production Capacity ◽  
Volumetric Method ◽  
Oil Field ◽  
Sequential Gaussian Simulation ◽  
Geological Model ◽  
Petrophysical Properties ◽  
Middle Region ◽  
Oil Reserves ◽  
Southern Area ◽  
Gaussian Simulation

Geological model construction is an important phase of reservoir study as the production capacity of a reservoir depends on its structural and petrophysical characteristics. The economic benefit of the reservoir is evaluated by estimating the formation petrophysical properties and calculating the oil reserves. East Baghdad southern area field is a newly developing oil field in the middle region of Iraq, where Khasib formation is its main reservoir. The aim of this study is to estimate the petrophysical properties and determine the pay units of the formation under study and the initial oil in place. Sequential Gaussian Simulation was used here to distribute the petrophysical properties as the statistical method and volumetric method was used to calculate the oil in place. The results show that the main reservoir units of the formation are K2 and K3 units, and the estimated oil reserves equal to 2179 mmSTB (346.43 million cubic meters).

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.

RESIDUAL OIL RESERVES GAS TREATMENT RESULTS FORECASTING IN CONDITIONS OF THE VOLGA-URAL OIL FIELDS

2020 ◽  
pp. 56-62
Author(s):  
A.P. Chizhov ◽  
◽  
A.V. Chibisov ◽  
V.E. Andreev ◽  
E.R. Efimov ◽  
...  
Keyword(s):  
Oil Fields ◽  
Residual Oil ◽  
Treatment Results ◽  
Gas Treatment ◽  
Oil Reserves

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

Detailed Facies Definition and 3D Static Model: Reservoir Management of the Eocene Producing Units in Block X of the Talara Basin in Northwest Peru

2010 ◽  
Author(s):  
Fabio Laverde ◽  
Gerardo Pozo ◽  
Flavio Miranda de Oliveira ◽  
Gonzalo Carrillo ◽  
Kevin Michael Torres ◽  
...  
Keyword(s):  
Reservoir Management ◽  
Static Model

Flow Assurance in Buzios Field: Key Challenges and Implemented Solutions

2021 ◽  
Author(s):  
Ivan Noville ◽  
Milena da Silva Maciel ◽  
Anna Luiza de Moraes y blanco de Mattos ◽  
João Gabriel Carvalho de Siqueira
Keyword(s):  
Liquid Flow Rate ◽  
Hydrate Formation ◽  
Oil Field ◽  
Oil Fields ◽  
Injection System ◽  
Flow Assurance ◽  
Water Alternating Gas ◽  
Early Design Stages ◽  
Scale Deposition ◽  
Full Operation

Abstract This article's goal is to present some of the main flow assurance challenges faced by PETROBRAS in the Buzios oil field, from its early design stages to full operation, up to this day. These challenges include: hydrate formation in WAG (Water Alternating Gas) operations; reliability of the chemical injection system to prevent scale deposition; increasing GLR (Gas Liquid Ratio) management and operations with extremely high flowrates. Flow assurance experience amassed in Buzios and in other pre-salt oil fields, regarding all these presented issues, is particularly relevant for the development of future projects with similar characteristics, such as high liquid flow rate, high CO2 content and high scaling potential.

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