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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractAlbacora Leste (ABL) Oil Field development, in Campos Basin, is based upon the exploitation of a heavy oil (16.5 to 21.5° API) from a miocene highly unconsolidated sandstone, which depositional model is interpreted as a complex turbidity system, mainly represented by channels, lobes and overbank facies. Water depth ranges from 800 to 2,000m and net thickness from 5 to 35m. The existing interbeds, both due to shale or dirty sands on the channel borders, give additional complexity to the well construction related to well placement strategy and sand control execution.The implementations made by the construction of 30 horizontal wells (being 16 producers and 14 injectors) are described in the paper. Amongst the most important items are the modifications on TSR, allowing one-trip production string installation, the massive application of front end directional and MWD/LWD technologies, resulting in successful landing and navigation in the reservoir, and the use of support ROV vessels to deploy and retrieve the transponders. All the above implementations increased reliability of offshore operations.The paper also describes the experience in integrated drilling and completion project (meaning integrated commitment from service companies) and the follow-up of a pending item list.As a main contribution to the industry, one can mention the implementation of a 'Torpedo Base' replacing jetting 30" casing, which reduces rig operational time. Furthermore, the use of light proppant, to pack the screens, opens up new horizons to the construction of long horizontal wells, which are highly desirable in the exploitation of future heavy oil fields.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractAlbacora Leste (ABL) Oil Field development, in Campos Basin, is based upon the exploitation of a heavy oil (16.5 to 21.5° API) from a miocene highly unconsolidated sandstone, which depositional model is interpreted as a complex turbidity system, mainly represented by channels, lobes and overbank facies. Water depth ranges from 800 to 2,000m and net thickness from 5 to 35m. The existing interbeds, both due to shale or dirty sands on the channel borders, give additional complexity to the well construction related to well placement strategy and sand control execution.The implementations made by the construction of 30 horizontal wells (being 16 producers and 14 injectors) are described in the paper. Amongst the most important items are the modifications on TSR, allowing one-trip production string installation, the massive application of front end directional and MWD/LWD technologies, resulting in successful landing and navigation in the reservoir, and the use of support ROV vessels to deploy and retrieve the transponders. All the above implementations increased reliability of offshore operations.The paper also describes the experience in integrated drilling and completion project (meaning integrated commitment from service companies) and the follow-up of a pending item list.As a main contribution to the industry, one can mention the implementation of a 'Torpedo Base' replacing jetting 30" casing, which reduces rig operational time. Furthermore, the use of light proppant, to pack the screens, opens up new horizons to the construction of long horizontal wells, which are highly desirable in the exploitation of future heavy oil fields.
The challenge of the alpha/beta waves gravel packing open hole in offshore Brazil is how to successfully displace the proppant slurry in a large wellbore with a low fracture gradient formation, deep to ultra-deep water depths, and extended reach horizontal section. Since 2001, job data from more than 72 open hole horizontal gravel packings have been compiled into a database. This paper reviews the well information and the key gravel packing parameters: pump rate, fluid density, injection proppant concentration, inner/outer annulus area ratio, dune ratio, packing rate, packing time and packing efficiency during alpha/beta waves. The engineering implementations and challenges, the best practices and lessons learned for open hole horizontal gravel packing are also summarized. The data analysis yields a better understanding about the open hole horizontal gravel packing in the Brazil offshore and provides a good guideline for future practice. A historical review is also presented showing how the gravel packing methodology has improved packing efficiency and success rate. Case histories are provided demonstrating how to deploy the single trip system and pack the extended reach wellbore utilizing ultra-light-weight (ULW) proppant under extreme with improved packing efficiency and the success rate. Introduction Deepwater exploration and production has developed over the last decade. There is a broadening of the geographic regions for deepwater completions (figure 1). The vast majority of the deepwater reserves are concentrated in the Gulf of Mexico, West Africa, Brazil, North Sea and South East Asia. The potential to achieve significantly higher sustainable production rates, well longevity and cost reduction have been the primary drivers for pursuing most deepwater completions. There have been many different types of completions in deepwater, however, the frac-packs and open hole horizontal completions have emerged as the two dominant completions. Appropriate applications are area dependent. In Brazil, the dominant completion type is the open hole horizontal gravel packing. In the Gulf of Mexico, 60% to 70% of completions are frac-packs. In West Africa both open hole completions and frac-packs are used. Based on published references 3 to 19, open hole horizontal gravel packing envelops, in terms of depth and the hole departure, are plotted in figures 2 and 3. The latest world record horizontal gravel pack was completed in a well with the departure length of 4206m and a departure ratio of 5 in the Captain Field in the North Sea.13 The open hole horizontal gravel packing completed in the deepest well was in the Campos Basin field of Brazil with sub-sea TMD of 5093m and TVD 3855m. Typical reservoirs in Campos Basin fields are high permeability turbidite sandstones with low API gravity oil. Generally, these unconsolidated formations are not strongly water driven. A high rate injection was needed to maintain reservoir pressure on these large producers. Several fields in the Campos Basin were developed with a series of horizontal producers and injectors. More than 200 open hole horizontal gravel packings have been completed since 1998 in Brail 1,2. Current gravel packing technology offers a good option for horizontal well completions where the problem is sand production. Key issues in project planning and execution of open hole horizontal gravel packing include reservoir study, shale stability study, formation integrity test, gravel pack sand sizing, gravel pack screen selection, workstring design, well displacement, and fluid loss control. The feasibility and success of gravel packing a long horizontal well depends on drilling techniques, drill-in fluids, wellbore clean-up, completions fluids, completion tools, equipment, sand control techniques, software/simulators, pumping schedules and field personnel experience. Challenges that can jeopardize performance of successful open hole horizontal gravel packing are excessive fluid loss, varying hole geometry that can lead to premature pack termination, hole stability issues leading to hole collapse, and a narrow pressure window between bottomhole pressure and fracture gradient. The beta-wave placement pressure is the main factor in determining the maximum length of a horizontal gravel pack. This pressure is limited by the requirement to install the gravel pack without exceeding formation fraction pressure.
Growing energy demand is leading the industry to re-evaluate resources found in challenging conditions such as unconventional gas formations, re-entry wells, and/or low producing wells. Cost-effective development of these resources depends on strategic application of advancing production solution technologies. To enhance production and improve recovery processes, more efficient perforating and fracturing methods have evolved along with advancements in wellbore production hardware via use of solid expandable tubulars or combinations of solid expandable and conventional tubulars.Expandable technology applied as a completion/production string facilitates increased fracturing rates, resulting in improved conductivity and enhanced hydrocarbon production. Expandable tubulars can be used in re-entry wells to isolate old perforations, allowing for new zones or new sections within zones to be perforated and stimulated. Either a combination tubular cladding system or a solid expandable system can provide an integral component in new wells or re-entry wells where low-permeability reservoirs, such as those characteristic of unconventional gas formations, require isolation and separation for selective or pinpoint hydraulic fracturing or re-fracturing.Although successful stimulation is routinely attained from hydraulic fracturing, ancillary downhole tools such as conventional completion equipment often compromise results by restricting flow and affecting pressure performance. Solid expandable systems can optimize the fracturing parameters by maintaining larger diameters and providing seals for selective multi-zone or zonal isolation purposes. These production systems can consist of either solid expandable tubulars or expandable sealing sections combined with conventional tubulars using premium connections, thus providing a superior completion solution.This paper will explain how solid expandable tubulars can be used to facilitate first-time fracturing, re-fracturing, and multi-zone fracturing, refurbishing older wells, and attaining large-diameter production/reservoir conduits. Integration and system development of this technology will be discussed. Case histories will be cited to illustrate the effectiveness of solid expandable systems in enhanced production and fracturing applications.
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