An Improved Methodology for Gas-Condensate Cluster Evaluations under Uncertainty

Abstract A decision to buy oil and gas assets requires a project evaluation (PE) aimed at integrated calculation of numerous possible scenarios of asset development, based on the uncertain resource values, variety of geological exploration program events, the most preferable decisions about the oil field development in the current economic conditions. The vast amount of calculations determined by the probabilistic nature of the PE and specific timeframes require optimization of the current approaches based on the balance between accuracy and time. This issue is particularly relevant for the evaluation and analysis of gas or gas-condensate field cluster as the profitability of the project can be concentrated in the asset integration into one production cluster. Such option as well as proposal to gather separate fields to the common infrastructure, sequence of fields development with different geological and physical characteristics, calculations of a large number of synergy options, etc. require the multi-disciplinary team to think outside the box while searching for a business case. Thus, this paper is aimed to improve current approaches and the current tools adaptation which will be used to drastically automate cross-functional probability estimate of gas field cluster with technical and economic justification of sustainable integrated solutions. The results were successfully validated within PE of several perspective gas condensate projects focused on the possibility of integration of the fields into a single cluster that creates additional value from the optimization of the project solutions (exploration, development strategy, gathering and transportation of hydrocarbons, monetization of the products) equal to tens of billions of rubles in a limited period of time.

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Economic Risk Analysis of Offshore Projects

Journal of Offshore Mechanics and Arctic Engineering ◽

10.1115/1.2919968 ◽

1992 ◽

Vol 114 (3) ◽

pp. 165-174 ◽

Cited By ~ 1

Author(s):

E. M. Bitner-Gregersen ◽

J. Lereim ◽

I. Monnier ◽

R. Skjong

Keyword(s):

Net Present Value ◽

Oil And Gas ◽

Development Project ◽

Oil Field ◽

Economic Risk ◽

Gas Field ◽

Cost Overruns ◽

Field Development ◽

Project Assessment ◽

Oil Field Development

A quantitative analysis of economic risk associated with large investments in offshore oil and gas field development and production is presented. The analysis is intended as a supporting tool in decision-making faced with uncertainty and risk, to study the effect of alternative decisions in an easy manner. The descriptors for the project assessment, such as the Internal Rate of Return (IRR) and Net Present Value (NPV) are applied. The study demonstrates first the impacts of early pilot production (EPP) prior to a main oil field development on the field economy of an oil field development and production installation. Furthermore, the result of cases which reflect relevant situations connected with cost overruns are presented, as well as derivation of rational decision criteria for termination/continuation of a project subjected to cost overruns. Finally, an oil field development project scheduling is demonstrated.

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HYDRODYNAMIC MODELING AS ONE OF THE DECISION METHODS FOR THE EFFICIENT DEVELOPMENT OF OIL FIELDS

Prospecting and Development of Oil and Gas Fields ◽

10.31471/1993-9973-2018-4(69)-7-14 ◽

2018 ◽

pp. 7-14

Author(s):

O. R. Kondrat ◽

O. A. Lukin

Keyword(s):

Work Experience ◽

Oil And Gas ◽

Main Tool ◽

Oil Field ◽

Oil Fields ◽

Real Field ◽

Gas Field ◽

Field Development ◽

Oil Field Exploitation ◽

Exploitation System

Oil production is a complex process that requires modern technologies, work experience and responsible personnel to implement cost-effective projects. Oil field exploitation processes stimulation or modeling is a method for researching exploitation objects on their analogs (models) in order to determine characteristics of available projected objects and make them distinct. The main objective of this research is to explore possibility and establishment of hydrodynamic stimulation results application effectiveness as a factor for decisions-making concerning oil or gas fields exploitation. The research, regarding optimization of oil field exploitation system, outlined the main directions and possibilities of oil extraction from depleted oil fields enhancement, and the hydrodynamic stimulation process as the main tool for solving such problems. The study of efficiency of oil and gas field development presupposed developing geological and technological model of a hypothetical deposit with technological indicators of a real Ukraine deposit. The hydrodynamic model was adapted for all wells according to actual data. All geological and technological measures, carried out in the sight, were also modelled. Field exploitation history was adapted. Oil field exploitation system was optimized by improving the reservoir pressure enhancement system in the real field. Different variants of field exploitation were considered. They include the conversion of the producing well in the injection well, whereas the well in the vaulted part is injected.

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OFFSHORE GIPPSLAND BASIN FIELDS

The APPEA Journal ◽

10.1071/aj70015 ◽

1971 ◽

Vol 11 (1) ◽

pp. 85 ◽

Cited By ~ 1

Author(s):

B. R. Griffith ◽

E. A. Hodgson

Keyword(s):

Lower Cretaceous ◽

Oil And Gas ◽

Oil Field ◽

Gas Field ◽

Field Development ◽

Oil And Gas Field ◽

Cumulative Production ◽

Gippsland Basin ◽

Offshore Field ◽

Unconformity Surface

The offshore Gippsland Basin, underlies the continental shelf and slope between eastern Victoria and Tasmania.The basin is filled with up to 25,000' of sediment, varying in age from Lower Cretaceous to Recent. The Lower Cretaceous section is represented by at least 10,000' of nonmarine greywackes of the Strzelecki Group. The overlying sediments of Upper Cretaceous to Eocene age comprise the interbedded sandstones, siltstones, shales and coals of the Latrobe Group, with a cumulative thickness of about 15,000'. Offshore, the Latrobe Group is overlain unconformably by up to 1500' of calcareous mudstones of the Lakes Entrance Formation and up to 5000' of Gippsland Limestone carbonates. Pliocene to Recent carbonates, reaching a maximum thickness of about 1000', complete the sedimentary section of the basin.Australia's first commercial offshore field, the Barracouta oil and gas field, was discovered in the Gippsland Basin in February 1965. Further exploratory drilling over the following two and a half years led to the discovery of the Marlin gas field and the Kingfish and Halibut oil fields.The principal hydrocarbon accumulations are reservoired by sediments of the Latrobe Group within closed structural highs on the Latrobe unconformity surface. Seal is provided by the mudstones and marls of the Lakes Entrance Formation and Gippsland Limestone.A field development programme was initiated immediately after Barracouta had been confirmed as a commercial gas reservoir. By the end of 1967, the Barracouta 'A' platform had been erected. Construction and positioning of the Marlin, Halibut and the two Kingfish platforms followed.To date development drilling has been completed on the Barracouta and Halibut fields, while development of the Marlin field has been temporarily suspended following completion of four wells. Development of the Kingfish oil field which commenced in March 1970, is still in a relatively early stage.The Barracouta field has been producing gas and oil since March and October, 1969 respectively. The Marlin gas field was put on stream in November, 1969 and the Halibut oil field in March 1970. As yet no wells drilled in the Kingfish oil field have been completed for production.The four fields provide a major source of hydrocarbons for the Australian market. By the end of September, 1970 cumulative production of sales quality gas from the Barracouta and Marlin fields was almost 23 BCF. Cumulative production of stabilised oil from Barracouta was 2 million barrels and over 26 million barrels from Halibut.

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Dynamics of hydrocarbon production in long-developed fields of the South Caspian basin with emphasis on reserves renewability

Journal of Petroleum Exploration and Production Technology ◽

10.1007/s13202-021-01094-5 ◽

2021 ◽

Vol 11 (3) ◽

pp. 1081-1091

Author(s):

A. A. Feyzullayev ◽

I. Lerche ◽

I. M. Mamedova ◽

A. G. Gojayev

Keyword(s):

Oil And Gas ◽

Methodological Approach ◽

Gas Production ◽

Oil Field ◽

Gas Condensate ◽

Caspian Basin ◽

The South ◽

South Caspian Basin ◽

Hydrocarbon Production ◽

Field Development

AbstractThe scientific basis of the paper is the concept of renewability of oil and gas resources. In accordance with this concept, the purpose of this paper is to estimate the volumetric rate of natural replenishment of the reservoir with oil and gas using the example of long-developed Bibieybat oil and Garadag gas condensate fields in the South Caspian Basin (SCB). The methodological approach of this assessment is based on the authors' assumption that at the late stage of field development, the recoverable amount of hydrocarbon fluids is compensated by the amount of their natural inflow, as a result of which oil or gas production stabilizes. The analysis of the dynamics of hydrocarbon production for the Bibieybat oil field covered the period from 1935 to 2018, and for the Garadag gas condensate field from 1955 to 1979. The rate of natural oil replenishment calculated for 29 operating facilities of the Bibieybat field varies per well within 0.32–1.4 ton/day (averaging 0.76 ton/day) or about 277 ton/year. The rate of natural gas inflow at the Garadag gas condensate field is about 5.2 thousand m3/day per well.

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Analysis of Dynamical Heat Conductivity of the Reservoir and Fluid Evacuation Zone on the Gas Condensate Well Flow Rate

J ◽

10.3390/j3010011 ◽

2020 ◽

Vol 3 (1) ◽

pp. 124-137

Author(s):

Kouadio Fabrice Anzian ◽

Mykhailo Illich Fyk ◽

Al-Sultan Mohammed Bassam ◽

Mohammed Khaleel Abbood ◽

Haval Mohammed Abdullatif ◽

...

Keyword(s):

Thermal Conductivity ◽

Oil And Gas ◽

Methodological Approach ◽

Field Evaluation ◽

Gas Condensate ◽

Bias Estimation ◽

Gas Field ◽

Field Development ◽

Oil And Gas Field ◽

Practice Methods

This study shows that the thermal conductivity of the rock borehole adjacent to the wells varies depending on the operation of the well. This is due to the fact that the actual temperature and temperature difference affect the humidity and other thermal properties of the rocks, which in turn affect the heat transfer coefficient across the section between the moving gas and the rocks. The static temperature field of primitive geothermal gradients acquires changes in a dynamic form. Theoretical consideration of changes in the thermal conductivity of rocks near the face and the wells is proposed to improve the prediction of gas condensate wells production. The result is achieved by introducing the specified equations of the thermal energy balance in the radial filtration and lifting of well products, which contain the coefficients of heat exchange and throttling. The refinement bias estimation of the 10%–15% level of gas condensate well extraction is shown using proposed methodological approach to relatively well-known (traditional in the field development practice) methods for estimating the extraction of a “medium well” from a particular oil and gas field evaluation. The results of this work demonstrate important scientific, applied, educational and methodological significance of using the methodology presented by the authors.

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The application of Mathematical Programming methods to oil and gas field development planning

Mathematical Programming ◽

10.1007/bf01589403 ◽

1988 ◽

Vol 42 (1-3) ◽

pp. 189-200 ◽

Cited By ~ 9

Author(s):

J. Sullivan

Keyword(s):

Mathematical Programming ◽

Oil And Gas ◽

Development Planning ◽

Gas Field ◽

Field Development ◽

Oil And Gas Field

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Study on the Characteristics of Well Completion Technology in Deepwater Oil and Gas Field Development

International Journal of Power and Energy Engineering ◽

10.53469/ijpee.2021.03(08).12 ◽

2021 ◽

Vol 3 (8) ◽

pp. 70-72

Author(s):

Jianbo Hu ◽

◽

Yifeng Di ◽

Qisheng Tang ◽

Ren Wen ◽

...

Keyword(s):

Deep Water ◽

Deep Sea ◽

Oil And Gas ◽

Gas Field ◽

Marine Research ◽

Field Development ◽

Research Technology ◽

Well Completion ◽

Development Capacity ◽

Exploration And Development

In recent years, China has made certain achievements in shallow sea petroleum geological exploration and development, but the exploration of deep water areas is still in the initial stage, and the water depth in the South China Sea is generally 500 to 2000 meters, which is a deep water operation area. Although China has made some progress in the field of deep-water development of petroleum technology research, but compared with the international advanced countries in marine science and technology, there is a large gap, in the international competition is at a disadvantage, marine research technology and equipment is relatively backward, deep-sea resources exploration and development capacity is insufficient, high-end technology to foreign dependence. In order to better develop China's deep-sea oil and gas resources, it is necessary to strengthen the development of drilling and completion technology in the oil industry drilling engineering. This paper briefly describes the research overview, technical difficulties, design principles and main contents of the completion technology in deepwater drilling and completion engineering. It is expected to have some significance for the development of deepwater oil and gas fields in China.

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Diagnostic Results of Current Distribution Injected Water Flow in the Productive Formation for Neft Dashlary Oilfield

10.2118/207058-ms ◽

2021 ◽

Author(s):

Khidir Mansum Ibragimov ◽

Nahide Ismat Huseinova ◽

Aliabas Alipasha Gadzhiev

Keyword(s):

Current Distribution ◽

Oil And Gas ◽

Experimental Studies ◽

Oil Field ◽

Fluid Distribution ◽

Field Development ◽

Hydrodynamic Parameters ◽

Oil And Gas Fields ◽

Oil Field Development ◽

Gas Fields

Abstract For controlling the oil field development proposed an economically efficient express calculation and visualization method of the hydrodynamic parameters current values distribution in the productive formation. The presented report shows the results of applying this technique for determining the injected water propagation direction into the productive formation (X horizon) at the «Neft Dashlary» field. Based on the calculated results, the current distribution of the injected water was visualized in the selected section of the formation. High accuracy of the calculation was confirmed by comparing obtained results with the results of a simultaneous tracer study conducted in the field conditions. During tracer studies it was tested a new tracer material, more effective than its analogs. According to laboratory and experimental studies, the addition of 0.003% of this indicator substance to the volume of injected water is the optimal amount for its recognition in the well's product. At the allocated area of the "Neft Dashlari" field, the benefits from the use of the calculation method amounted to 62.9 thousand manats. Based on the obtained satisfying results of the new method for calculating hydrodynamic parameters and the use of a tracer indicator application at the «Neft Dashlary» oilfield, it is recommended to apply these developments in other oil and gas fields for mass diagnostic of the reservoir fluid distribution in a selected area of productive formations.

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