Novel Cost Effective Installation Approach for a Marginal Field. The Lufeng 22-1 Field Development in China.

1997 ◽  
Author(s):  
Sitham Pillai
Keyword(s):  
Cost Effective ◽  
Field Development ◽  
Marginal Field

Three-Column TLP Concept for Marginal Field Development

2009 ◽  
Author(s):  
Neil Williams ◽  
Homayoun Heidari ◽  
Sean Large
Keyword(s):  
Equilateral Triangle ◽  
Cost Effective ◽  
Technical Development ◽  
Effective Solution ◽  
Field Development ◽  
Geometric Center ◽  
Marginal Field ◽  
Rectangular Columns

This paper discusses the development of a new self-stable TLP concept for marginal field applications. This concept — called ThreeStar™ — is based on three rectangular columns arranged at the vertices of an equilateral triangle and battered towards its geometric center. The columns are joined by conventional rectangular pontoons. The reduced number of tendons/piles relative to a conventional four column TLP makes the ThreeStar a cost-effective solution in applications where the production riser count is relatively low or the topsides payload is small. This paper presents a description of the technical development of the ThreeStar TLP and outlines the unique features of the concept. The relative merits of the ThreeStar over comparable four-column TLPs for different environments and payload ranges are discussed. Finally, ThreeStar systems are presented for two example deepwater applications.

THE COBIA 2 SUBSEA COMPLETION

1984 ◽  
Vol 24 (1) ◽  
pp. 153
Author(s):  
M. N. Shaw
Keyword(s):  
Crude Oil ◽  
Safety Valve ◽  
Effective Means ◽  
Cost Effective ◽  
The Novel ◽  
Successful Operation ◽  
Field Development ◽  
Coiled Tubing ◽  
The World ◽  
Marginal Field

Subsea completions are recognised worldwide as a cost effective means of developing marginal reservoirs, accelerating production and draining reservoir extremities which cannot be reached from conventional platforms. To date, more than 280 subsea completions have been installed around the world. Cobia 2, the first subsea completion in Australian waters, commenced production in Bass Strait in June 1979. It continued to produce until April 1983, when it was shut-in following the commencement of production from the Cobia platform. In its four years of operation, the well produced over 280 megalitres (1.78 million barrels) of crude oil, with peak well rates reaching as high as 750 kilolitres per day in the latter stages of its producing life. Overall, Cobia 2 has been a technical and commercial success.The need for regular pumpdown or TFL ('through flowlines') wax-cutting operations in the flowlines to maintain high levels of production generated a great deal of confidence in the use of TFL techniques for routine and non-standard subsea well servicing. In an industry 'first', TFL methods were developed to lock open and seal a leaking subsurface safety valve and, within it, set a special insert subsurface safety valve. This work allowed the well to be returned to production in a situation where a conventional workover of the well was not feasible.Other well-servicing techniques developed during the Cobia 2 project involved the novel use of a coiled tubing unit to retrieve TFL tools which had become stuck in the flowlines during the wax-cutting operations.The highly successful operation of Cobia 2 has proved the viability of this type of completion for marginal field development in Australia.

M-9 Zawtika Marginal Field Development Study

2017 ◽  
Author(s):  
L. Chaowarit ◽  
H. Pongpat ◽  
P. Korakote ◽  
O. Pariyachat ◽  
H. Pithak ◽  
...  
Keyword(s):  
Development Study ◽  
Field Development ◽  
Marginal Field

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.

Planning and Technology Utilization: A Holistic Approach to Marginal Field Development

2016 ◽  
Author(s):  
M Wilkins ◽  
S Pambayuning ◽  
R Watcharanantakul ◽  
S Thepparak ◽  
S Opdal ◽  
...  
Keyword(s):  
Holistic Approach ◽  
Technology Utilization ◽  
Field Development ◽  
Marginal Field

Abandonment Best Practices in Unitised Area for Wells and Facilities Straddling Two Countries in Malay Basin: A Case Study

2021 ◽  
Author(s):  
Kumar Nathan ◽  
M Arif Iskandar Ghazali ◽  
M Zahin Abdul Razak ◽  
Ismanto Marsidi ◽  
Jamari M Shah
Keyword(s):  
Oil And Gas ◽  
Late Life ◽  
Cost Effective ◽  
Successful Outcome ◽  
Maintenance Cost ◽  
Gas Field ◽  
Field Development ◽  
Host Government ◽  
Cycle Oil

Abstract Abandonment is considered to be the last stage in the oil gas field cycle. Oil and gas industries around the world are bounded by the necessity of creating an abandonment program which is technically sound, complied to the stringent HSE requirement and to be cost-effective. Abandonment strategies were always planned as early as during the field development plan. When there are no remaining opportunities left or no commercially viable hydrocarbon is present, the field need to be abandoned to save operating and maintenance cost. The cost associated on abandonment can often be paid to the host government periodically and can be cost recoverable once the field is ready to be abandoned. In Malaysia, some of the oil producing fields are now in the late life of production thus abandonment strategies are being studied comprehensively. The interest of this paper is to share the case study of one of a field that is in its late life of production and has wells and facilities that planned to be abandon soon. The abandonment in this field is challenging because it involves two countries, as this field is in the hydrocarbon structure that straddling two countries. Series of techno-commercial discussion were held between operators of these two countries to gain an integrated understanding of the opportunity, defining a successful outcome of the opportunity and creating an aligned plan to achieve successful abandonment campaign. Thus, this paper will discuss on technical aspects of creating a caprock model, the execution strategies of abandoning the wells and facilities and economic analysis to study whether a joint campaign between the operators from two countries yields significantly lower costs or otherwise.

Challenges of Developing Marginal Fields in the Current Climate of Oil and Gas Industry

2021 ◽  
Author(s):  
Amina Danmadami ◽  
Ibiye Iyalla ◽  
Gbenga Oluyemi ◽  
Jesse Andrawus
Keyword(s):  
Oil And Gas ◽  
Dynamic Environment ◽  
Poor Performance ◽  
Oil And Gas Industry ◽  
Economic Benefits ◽  
Gas Industry ◽  
Field Development ◽  
Quality Technology ◽  
Indigenous Participation ◽  
Marginal Field

Abstract Marginal field development has gained relevance in oil producing countries because of the huge potential economic benefits it offers. The Federal Government of Nigeria commenced a Marginal Fields program in 2001 as part of her policy to improve the nation’s strategic oil and gas reserves and promote indigenous participation in the upstream sector. Twenty years after the award of marginal fields to indigenous companies to develop, 50% have developed and in production, 13% have made some progress with their acquisition while 37% remain undeveloped. The poor performance of the marginal field operators is due to certain challenges which have impeded their progress. A review of challenges of developing marginal fields in the current industry climate was conducted on marginal fields in Nigeria to identify keys issues. These were identified as: funding, technical, and public policy. Considering the complex, competitive and dynamic environment in which these oil and gas companies operate, with competition from renewables, pressure to reduce carbon footprint, low oil price and investors expectation of a good return, companies must maintain tight financial plan, minimize emissions from their operations and focus on efficiency through innovation. The study identifies the need for a decision-making approach that takes into consideration multi criteria such as cost, regulation, quality, technology, security, stakeholders, safety and environment, as important criteria based on which to evaluate the selection of appropriate development option for marginal fields.

Produced Water Handling Using Downhole Oil Water Separation Study Case Onshore & Offshore Fields Abu Dhabi

2021 ◽  
Author(s):  
Abdelhak Ladmia ◽  
Dr. Younes bin Darak Al Blooshi ◽  
Abdullah Alobedli ◽  
Dragoljub Zivanov ◽  
Myrat Kuliyev ◽  
...  
Keyword(s):  
Produced Water ◽  
Operating Cost ◽  
Cost Effective ◽  
Management Tool ◽  
Water Separation ◽  
Field Development ◽  
Effective Manner ◽  
Oil Water Separation ◽  
Oil Water

Abstract The expected profiles of the water produced from the mature ADNOC fields in the coming years imply an important increase and the OPEX of the produced and injected water will increase considerably. This requires in-situ water separation and reinjection. The objective of in-situ fluid separation is to reduce the cost of handling produced water and to extend the well natural flow performance resulting in increased and accelerated production. The current practice of handling produced water is inexpensive in the short term, but it can affect the operating cost and the recovery in the long term as the expected water cut for the next 10-15 years is forecasted to incease significantly. A new water management tool called downhole separation technology was developed. It separates oil and & gas from associated water inside the wellbore to be reinjected back into the disposal wells. The Downhole Oil Water Separation (DHOWS) Technology is one of the key development strategies that can reduce considerable amounts of produced water, improve hydrocarbon recovery, and minimize field development cost by eliminating surface water treatment and handling costs. The main benefits of DHOWS include acceleration of oil offtake, reduction of production cost, lessening produced water volumes, and improved utilization of surface facilities. In effect, DHOWS technologies require specific design criteria to meet the objectives of the well. Therefore, multi--discipline input data are needed to install an effective DHOWS with a robust design that economically outperforms and boosts oil and/or gas productions. This paper describes the fundamental criteria and workflow for selecting the most suitable DHOWS design for new and sidetracked wells to deliver ADNOC production mandates in a cost-effective manner while meeting completion requirements and adhering to reservoir management guidelines.

Sign in / Sign up

Export Citation Format

Share Document