Offshore Gas Field Development Strategy and Flow Assurance Prediction and Optimization in Harsh Environment

2018 ◽  
Author(s):  
Humoud Almohammad ◽  
Abdullah Al-Derbass ◽  
Abdulaziz Alsubaie ◽  
Mohammed Bumajdad ◽  
Abdulaziz Al-Khamis ◽  
...  
Keyword(s):  
Development Strategy ◽  
Harsh Environment ◽  
Flow Assurance ◽  
Gas Field ◽  
Field Development

Flow Assurance Challenges for China’s First Deepwater Gas Field Development in South China Sea

2020 ◽  
Author(s):  
Lawrence Khin Leong Lau ◽  
Kun An ◽  
Xian Di Tang ◽  
Fei Jian Luo ◽  
Yang Yang ◽  
...  
Keyword(s):  
South China Sea ◽  
South China ◽  
Flow Assurance ◽  
Gas Field ◽  
Field Development ◽  
China Sea

scholarly journals Economic Evaluation of Y Gas Field Development Using Reservoir Simulator

2018 ◽  
Vol 1 (3) ◽  
Author(s):  
Anita Theresa Panjaitan ◽  
Rachmat Sudibjo ◽  
Sri Fenny
Keyword(s):  
Development Strategy ◽  
Reservoir Simulation ◽  
Gas Field ◽  
Field Development ◽  
Development Scenarios ◽  
Black Oil ◽  
Simulation Results ◽  
Reservoir Simulation Model ◽  
Attractive Case ◽  
Reservoir Simulator

<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>

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

2017 ◽  
Author(s):  
Ming Zhang ◽  
Longxin Mu ◽  
Chunlei Li ◽  
Kening Zheng ◽  
Lijiang Duan ◽  
...  
Keyword(s):  
Development Strategy ◽  
The South ◽  
Gas Field ◽  
Field Development

An Improved Methodology for Gas-Condensate Cluster Evaluations under Uncertainty

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.

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

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.

Technology Innovations of the Flow Assurance System in the Development of the Liwan 3-1 Deepwater Gas Field

2013 ◽  
Author(s):  
Qingping Li ◽  
Haiyuan Yao ◽  
Kai Wang
Keyword(s):  
Multiphase Flow ◽  
System Design ◽  
Southern China ◽  
Flow Assurance ◽  
Gas Oil ◽  
Gas Field ◽  
Field Development ◽  
Technology Innovations ◽  
Forecast Control ◽  
And Control

As we know, the Liwan3-1 gas field is the first deepwater gas field with water depth 1480m in the Southern China Sea. The seabed temperature is only 3–4 °C. Moreover, the complex of the gas oil and water multiphase flow, seabed hypsographic feature and operation activities etc., bring a series of problems to subsea transportation system, such as solid formation (hydrate, wax), severe slug flow in deep water riser, multiphase flow corrosions and solid particle’s erosion etc. This paper briefly summarizes the typical flow assurance innovation technologies related to the Liwan3-1 gas field, include the layout of Liwan3-1 deepwater subsea production system, the dual-pipe 79km-length subsea tied back system design, the hydrate forecast and control technology, slug forecast-control and pigging method for the subsea tied back system along the slope, the gas recycle system design for low production rate. Also, the potential gas field development and flow management technologies are also discussed in this paper.

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

2012 ◽  
Author(s):  
Feng Wang ◽  
Yingan Zhang ◽  
Guangyu Liu ◽  
Zhaopeng Zhu ◽  
Biansheng Li ◽  
...  
Keyword(s):  
Development Strategy ◽  
Tight Gas ◽  
Gas Field ◽  
Field Development

Optimization Applied to Buzios Flexible Riser Systems and Subsea Layout

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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