Mature Condensated Gas Field Development Strategy: An Integration of Geophysics, Geology and Log for the South Sumatra Basin, Indonesia

<p>Y Field which located around 28 km south east of Jakarta was discovered in 1989. Three wells have been drilled and suspended. The initial gas ini place (IGIP) of the field is 40.53 BSCF. The field will be developed in 2011. In this study, reservoir simulation model was made to predict the optimum development strategy of the field. This model consisted of 1,575,064 grid cells which were built in a black oil simulator. Two field development scenarios were defined with and without compressor. Simulation results show that the Recovery Factor at thel end of the contract is 61.40% and 62.14% respectively for Scenarios I and II without compressor. When compressor is applied then Recovey Factor of Scenarios I and II is 68.78% and 74.58%, correspondingly. Based on the economic parameters, Scenario II with compressor is the most <br />attractive case, where IRR, POT, and NPV of the scenario are 41%, 2.9 years, and 14,808 MUS$.</p>

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An Improved Methodology for Gas-Condensate Cluster Evaluations under Uncertainty

10.2118/206572-ms ◽

2021 ◽

Author(s):

Sergei Igorevich Melnikov ◽

Nikita Vladimirovich Vershigora ◽

Alexander Alexandrovich Groo ◽

Denis Sergeevich Grigorev ◽

Pavel Yurievich Kiselev ◽

...

Keyword(s):

Development Strategy ◽

Oil And Gas ◽

Business Case ◽

Oil Field ◽

Gas Condensate ◽

Gas Field ◽

Field Development ◽

Asset Development ◽

Additional Value ◽

Probabilistic Nature

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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Geological Model Coupled with Geomechanics Makes an Impact on Fracturing Stimulation and Field Development Strategy of a Tight Gas Formation in the Sultanate of Oman

10.2118/spe-172949-ms ◽

2015 ◽

Author(s):

Kevin Bate ◽

Mauricio Lane ◽

Alexey Moiseenkov ◽

Sergey Nadezhdin

Keyword(s):

Development Strategy ◽

Fracture Propagation ◽

Radioactive Tracer ◽

Hydraulic Fractures ◽

Tight Gas ◽

Reservoir Properties ◽

Gas Field ◽

Field Development ◽

Tight Gas Formation ◽

The Individual

Abstract Appraisal drilling of a recently discovered Cambrian-aged gas field in Oman is indicating that the field may have significant amounts of gas locked in a challenging deep, hot, and highly pressured reservoir environment. The low porosity and permeability values of the Amin reservoir allow the classification of the reservoir as a tight gas sand. The variability of reservoir properties, both spatially and vertically, makes it difficult to standardize perforation and fracture stimulation design which, in turn, complicates delineation of a development plan for the project. One of the difficulties relates to uncertainty in vertical propagation of hydraulic fractures. Fracture height based on evaluation of radioactive tracer logs indicates that vertical barriers to fracture propagation may relate to specific geologic zones in the reservoir. The mapping of the reservoir zones into undeveloped areas of the field would allow selection of primary and secondary production targets based on the specific physical properties of the individual zones. To assume that no barrier to fracture propagation exists between separate production units may lead to attempts to stimulate them synchronously, which would be disadvantageous for several reasons, such as premature screenouts and incomplete coverage of gas-bearing layers. Reserves booking and allocation can also be jeopardized should the fractures propagate into undesired zones.

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The Horizontal Massive Multistage Fracturing Meet the Changling Tight Gas Field Development Strategy

10.2118/155911-ms ◽

2012 ◽

Cited By ~ 1

Author(s):

Feng Wang ◽

Yingan Zhang ◽

Guangyu Liu ◽

Zhaopeng Zhu ◽

Biansheng Li ◽

...

Keyword(s):

Development Strategy ◽

Tight Gas ◽

Gas Field ◽

Field Development

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Geomechanical justification of security measures in the development of the South Khingan deposit of manganese ore

E3S Web of Conferences ◽

10.1051/e3sconf/20185602014 ◽

2018 ◽

Vol 56 ◽

pp. 02014

Author(s):

Maksim Rasskazov ◽

Marina Potapchuk ◽

Gennady Kursakin ◽

Denis Tsoy

Keyword(s):

Physical And Mechanical Properties ◽

Rock Massif ◽

Manganese Ore ◽

Security Measures ◽

The South ◽

Rockburst Hazard ◽

Field Development ◽

Stage Of Development ◽

Geological Conditions ◽

Numerical Simulation Methods

The paper presents the results of geomechanical studies on the assessment of the potential rockburst hazard of the rock massif of the South Khingan deposit of manganese ore at the stage of development. Geodynamic zoning has been performed, mining and technical, mining and geological conditions of field development have been studied, and parameters of physical and mechanical properties of enclosing rocks and ores have been determined. Numerical simulation methods have been used to estimate the stress state of a rock massif at various stages of the deposit development. The tendency of the lower part of the South Khingan deposit to rockburst has been established. The complex of effective organizational and technical security measures has been substantiated in the development of this field.

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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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Optimization Applied to Buzios Flexible Riser Systems and Subsea Layout

10.4043/30972-ms ◽

2021 ◽

Author(s):

Vinicius Gasparetto ◽

Thierry Hernalsteens ◽

Joao Francisco Fleck Heck Britto ◽

Joab Flavio Araujo Leao ◽

Thiago Duarte Fonseca Dos Santos ◽

...

Keyword(s):

Deep Water ◽

Technology Use ◽

Capital Expenditure ◽

Lessons Learned ◽

Internal Diameter ◽

Flexible Riser ◽

Flexible Pipe ◽

Injection Wells ◽

Gas Field ◽

Field Development

Abstract Buzios is a super-giant ultra-deep-water pre-salt oil and gas field located in the Santos Basin off Brazil's Southeastern coast. There are four production systems already installed in the field. Designed to use flexible pipes to tie back the production and injection wells to the FPSOs (Floating Production Storage and Offloading), these systems have taken advantage from several lessons learned in the previous projects installed by Petrobras in Santos Basin pre-salt areas since 2010. This knowledge, combined with advances in flexible pipe technology, use of long-term contracts and early engagement with suppliers, made it possible to optimize the field development, minimizing the risks and reducing the capital expenditure (CAPEX) initially planned. This paper presents the first four Buzios subsea system developments, highlighting some of the technological achievements applied in the field, as the first wide application of 8" Internal Diameter (ID) flexible production pipes for ultra-deep water, leading to faster ramp-ups and higher production flowrates. It describes how the supply chain strategy provided flexibility to cover the remaining project uncertainties, and reports the optimizations carried out in flexible riser systems and subsea layouts. The flexible risers, usually installed in lazy wave configurations at such water depths, were optimized reducing the total buoyancy necessary. For water injection and service lines, the buoyancy modules were completely removed, and thus the lines were installed in a free-hanging configuration. Riser configuration optimizations promoted a drop of around 25% on total riser CAPEX and allowed the riser anchor position to be placed closer to the floating production unit, promoting opportunities for reducing the subsea tieback lengths. Standardization of pipe specifications and the riser configurations allowed the projects to exchange the lines, increasing flexibility and avoiding riser interference in a scenario with multiple suppliers. Furthermore, Buzios was the first ultra-deep-water project to install a flexible line, riser, and flowline, with fully Controlled Annulus Solution (CAS). This system, developed by TechnipFMC, allows pipe integrity management from the topside, which reduces subsea inspections. As an outcome of the technological improvements and the optimizations applied to the Buzios subsea system, a vast reduction in subsea CAPEX it was achieved, with a swift production ramp-up.

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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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