This paper describes the successful delivery of one ultrahigh-rate gas well (more than 250 MMscf/D) completed in a significant gas field offshore Israel with 7-in. In this paper, gravel-pack pore size is evaluated further by use of the permeability of the gravel pack and other methods. A new sizing method is proposed that is based on the effective formation size and the gravel-pack pore size. An operator successfully executed two wireline through-tubing gas-shutoff (GSO) workovers in high-angle openhole-gravel-pack (OHGP) completions to isolate high-gas/oil-ratio (HGOR) zones, resulting in significantly increased oil production.
The oil and gas industry is moving towards deepwater exploration as cost optimisation, through a period of low priced oil, has ensured deepwater explorations and production become more viable. Currently, offshore production facilities in Myanmar exists in both shallow and medium water depths; however, the potential of frontier deepwater exploration are available within the Myanmar offshore blocks. Future deepwater activities will create opportunities in Myanmar especially in end-to-end exploration and production (E&P), and throughout its value and supply chain. In the long run, the emphasise of the industry will include a digitally and technologically enhanced approach to deepwater E&P; while taking an in-depth, methodological and systems-based field development; subsea wellhead completion, asset integrity and more. At the same time, the support system to deepwater E&P must also be developed to ensure that the industry meet regulatory, logistical, environmental, and infrastructure challenges in the Myanmar operations.
This workshop is intended to address all types of stimulation practices used in both the North Sea and in continental Europe. To achieve a fruitful discussion, workshop sessions have been designed to address both the very specific technical challenges and the fundamental questions pertaining to stimulation in a sensitive land and offshore environment. Optimising stimulation treatments in these economically challenging times, in both a technically and environmentally challenging arena, requires special considerations. The participation of major and independent operating companies and service companies will allow a wide sharing of views, experiences, and opinions on how to proceed toward successfully meeting all well objectives. The objective of this workshop is to bring together a broad cross-section of people actively involved in stimulation design and implementation within the region, while also introducing a select number of global stimulation specialists who will share their experiences.
This session addresses the challenges of staying above saturation pressure and/or maximizing recovery of the most valuable components for as long as possible, for the entire unit. Additionally, the strategy must include data acquisition and be executed within the confines of reasonable capital requirements, and without significant well intervention. Reservoir & well pressure management issues d. Mature unconventional production wells experience substantial production declines and were likely stimulated less optimally than newer wells. Rather than simply drilling more wells, this has led operators to look to restimulation of wells with reduced production rates and lesser stimulated reservoir volume.
The depressed oil price has spurred a new wave of innovation in oil and gas industry. When a barrel of oil fetched $100 or more, energy companies were focused on drilling wells and pumping crude oil as fast as they could. However, with oil price has settled around $50 a barrel these days, companies are focused on efficiency; getting the most petroleum for the least amount of money. And many are turning to advanced technology or innovation for help. This session will focus on innovative approaches to reduce cost for mature assets to sustain field life including technology, well types, business model, and resource management. This session also aims to address topics on improving recovery factor through innovative activities in production enhancement and optimization, and tertiary recovery method.
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Coiled tubing supports fracturing operations in a variety of situations, including preparation of the wellbore, manipulation of downhole equipment and millout of plugs. Since early 2011 coiled tubing has gained momentum for annular treatments and fracturing through coiled tubing. The advent of coiled tubing actuated sleeves helped operators complete wells with minimum post stimulation intervention. Coiled tubing can also be used in combination with downhole assemblies such as straddle packers for re-fracs, which have helped operators optimise existing completions. In recent occasions, the use of “intelligent” coiled tubing systems enabled comprehensive diagnostics pre/post stimulation. The challenges of deviated wells further emphasise the need for a solution that can be deployed rapidly and cost-effectively with broad operational boundaries to support the development of unconventional resources. This session will discuss the latest developments and field applications of coiled tubing as intervention method for fracturing operations.
This panel session will highlight and discuss high-level approaches to innovation in gas field development which may provide opportunities for enhanced cost efficiency and risk management. We will explore key issues faced by gas project developers and identify innovative solutions to support long-term gas field value whilst meeting regulatory requirements and societal expectations. The panel will share their experience in meeting these challenges against a backdrop of a continually changing business environment.
Imbazi, Oyeintonbra (Shell Company in Nigeria) | Ugoh, Oluwatobi (Shell Company in Nigeria) | Okoloma, Emmanuel (Shell Company in Nigeria) | Osuagwu, Micheal (Shell Company in Nigeria) | Enyioko, Chigoziem (Halliburton) | Ighavini, Emmanuel (Halliburton) | Uzodinma, Chioma (Halliburton)
Well 01 and Well 02 are part of the phase 1-6 project that involved the development of six wells with the potential to deliver an additional 70% production increase to the LNG export market. The sand face for both wells was drilled with 0.72psi/ft pseudo oil-based mud (POBM). After the initial well clean-up, both wells produced sub-optimally (~20% of estimated potential) with relatively high drawdown (ranging from 500psi – 1000psi). This low production was suspected to be because of downhole (screen and formation) impairment or partial opening of the formation isolation valves (FIV).
A restoration team was set up with a responsibility to proffer a robust well intervention execution plan and select the most potent barite dissolver. Nine stimulation chemicals were tested and based on the team criteria, CHEM-001 and CHEM-002 were selected as main-treatment and pre-flush chemicals, respectively.
The downhole and surface conditions that exist in deep high-pressure wells pose many challenges to the coiled tubing industry as it strives to provide safe and reliable access to the wells. This paper highlights a case history of successfully snubbing coiled tubing (CT) into two deep (about 14,000ft+) live wells (Well 01 and Well 02) with a high surface pressure (7000psi+) and temperature (80 – 100°C) to stimulate both wells. The success criteria post stimulation was targeted at 75% of the potential production value. However, post treatment results show that cumulative gas production increased by 375% (with about 200psi) with a potential to increase up to 400%.
This paper details the entire operations during the CT well intervention, the planning, design, and technical analysis which led to the selection of a CT with 130,000psi yield strength on a 125K CT injector system, force simulations, and laboratory tests on CT with stimulation chemicals which led to a successful stimulation campaign. The paper also covers the initial planned versus actual operations and the lessons learned leading to on-the-spot optimization plans that resulted in a highly successful intervention operation.