Delivering wells capable of high rate and high ultimate recovery heavy oil is one of the key requirements for success of the Ultra-deepwater Parque das Conchas development in block BC-10, Campos Basin, Brazil. This paper presents the Parque das Conchas well design to achieve these objectives while tackling key challenges such as shallow reservoir setting below mud line and low fracture gradient setting. It explains fabrication and final preparation efforts followed by a detailed description of execution efforts on the Transocean mobile drilling unit Arctic-1, including performance and learnings by well section. The Parque das Conchas well design and execution efforts have resulted in several significant results to date:Two of the longest horizontal open hole wells successfully drilled and completed with a full-length alpha and alpha/beta wave gravel pack in Brazil at 1,115 and 1,160m.Top quartile drilling and completion times.Use of the Transocean Arctic-1 with a surface BOP (SBOP) system (Ref 1).Promising well performance from initial production. For the drilling and completion of the Parque das Conchas wells a combination of existing and new technologies have been used. New technologies include the SBOP system, Spacer Spool, Collapsible 9-5/8" Casing Shoe Joint, 4-1/4" washpipe, tailpipe swell element and premium sand control screens with extensive mesh size QA/QC. Existing technologies are point the bit rotary steerable, Production Screen Tested (PST) drilling fluid, Alpha Wave Gravel Packing, Delayed Filtercake Breakdown system and Fluid Loss Valve (FLV) lower completion isolation. Well construction results have been excellent to date with the wells delivered on time, within budget and with productivity indices exceeding expectations. Credit goes to a team of people working closely together across disciplines in wells, subsurface, subsea, production operations, HSE, logistics, finance and QA/QC departments, across a global team. Introduction The BC-10 block is located in the Campos Basin approximately 120 km southeast from the city of Vitoria off the coast of Brasil. Water depths in this ultra deepwater block range from 1,400 to 2,000 m. Shell is the operator with a 50% interest in a joint venture with Petrobras and ONGC with 35% and 15% interest, respectively. A total of 14 exploration and appraisal wells have been drilled to date, which discovered and appraised 5 oil accumulations in the BC-10 block. In June 2006 field development plans were submitted to the ANP for the development of the Ostra, Abalone and Argonauta-BW and Argonauta-ON fields. Phase 1 of the project comprises the development of the first three fields. Argonauta-ON is planned as part of Phase 2. Given waterdepths, shallow below mudline hydraustatically pressurized reservoirs and oil properties a combination of long horizontal wells and artificial lift are required to deliver and maintain economic rates.

The Parque das Conchas development is located in the BC-10 block 75 miles southeast of Vitoria int the Campos Basin, offshore Brazil. Shell is the operator with a 50% equity share, with joint venture partners Petrobras (35%) and ONGC (15%). The current development consists of three hydrostatically pressurized medium to heavy oil reservoirs (Abalone, Ostra and Argonauta B West) in water depths ranging from 5430 ft to 6310 ft (1655 m to 1923 m). One of the key enabling technologies at the heart of the subsea system infrastructure is the mudline boosting system consisting of Modulo de Bombeio or Pumping Unit (MOBO) caisson ESPs installed inside Artificial Lift Manifolds (ALMs) 1) . Oil from the individual subsea wells flows into the MOBO caisson ESPs and from there the ESPs pump the oil up to the floating production, storage and offloading (FPSO) vessel. The ALMs are located approximately 5½ miles (8.85 km) from the FPSO (see Figs. 1 and 2). This paper will describe how the design for these special longlife ESPs was developed, how a stack-up test was performed on land in the US, and how the pumps were deployed in the field. In the second part, the first operations for pulling two of the ESPs are described. The whole assembly consisting of the MOBO, 32-in. caisson and ESP completion was lifted in open water to the rig with a total assembled weight of 169 tons (171.7 metric tons). Figure 1: BC-10 Field layout overview.

The Parque das Conchas project is located in the BC-10 deepwater block in the Campos Basin, approximately 120 km southeast from the city of Vitoria, in water depths of 1,500 to 2,000 meters. Shell is the operator with a 50% equity share, with joint venture partners Petrobras (35%) and ONGC (15%) 17 . The wells flow via Caisson ESP's to a host FPSO. Horizontal Open-hole Gravel Pack was the sand control method selected in the low frac margin reservoirs of the Ostra Field. In preparation for completing wells in formations with anticipated sand production, a large laboratory study was conducted evaluating the performance of stand-alone woven mesh screens and gravel packs. The study was performed to select a premium mesh screen which would minimize solids production in the event of incomplete gravel pack and manage fines production that would pass through the seabed located Caisson ESP systems. Additionally, it was important to control solids production to the Floating Production, Storage and Offloading (FPSO) unit as there were no provisions installed to handle large volumes of solids at the surface. The test grid compared the performance of multiple screen sizes with and without gravel packs with three unconsolidated formation particle size distributions which were representative of the size distributions anticipated in the completions. The resulting performance data correlated the amount of solids production, size of produced solids, retained gravel pack permeability and retained screen permeability as functions of the effective size of the formation material, the gravel size and the pore size of the screen. The gravel pack media size and premium screen mesh size were selected based on the results of this testing. Screen QA/QC was determined to be critical in the event a full gravel pack was not achieved and the screens would be expected to provide sand control in a stand-alone mode. An enhanced quality process was developed and implemented to ensure the highest quality of the screens was maintained and materials were traceable during well sand control completions.The laboratory tests identified combinations of screen and gravel packs which appeared to indicate the best choice for controlling solids production in an acceptable range while maintaining high flow capacity, maximizing production at minimum drawdown pressures. An enhanced QA/QC process for screen manufacturing contributed to the success of the completions. Production history for the first 2 years indicates minimal sand production.

In order to economically develop the Albian Carbonate Macae formation in the Campos Basin Deepwater Brazil an extended reach horizontal well is required. Due to the tight nature (low permeability) of the rock, stimulation of the reservoir is required. Completion designs and techniques for treating extended reach horizontal wells in deepwater are limited. Most applications for these type wells in Deepwater are ineffective (high skin/low PI) and inefficient (trip/time intensive) affecting project economics. A completion system was developed that allows for safe, effective and efficient stimulation and installation of such an extended reach horizontal well in Deepwater. This paper will describe the design, testing and execution of a unique Deepwater completion system that adapts a known multi-stage ball drop system used in onshore unconventional reservoirs, for example the US and Canada, to a known horizontal open hole sand control system to effectively matrix acidize a 2000 m horizontal open hole thru a Limited Entry Liner with reservoir segmentation. The system uses a Retrievable Ball Drop Diversion System (RBDDS) consisting of multi-stage frac sleeves run on wash pipe. The RBDDS is run inside a limited entry liner that is segmented into stages or intervals by openhole programmable interventionless packers (Mendes et al. 2014) all run in a single trip and with no pipe manipulation required while stimulating. It furthermore leaves behind a robust lower completion system for the life of the field. This 2000 m lower completion system was successfully run in the Albian Carbonate reservoir and all stages treated with 15% HCl with minimal NPT, no harm to people or environment. At the time of completion, this well was the longest horizontal reservoir section and longest step out well drilled and completed in Brazil. This Limited Entry Liner System together with the RBDDS proved to be a very efficient, effective and deepwater friendly system. Introduction Low permeable deepwater carbonate reservoirs have created many challenges to produce economically. The wells typically require extensive reservoir contact that has to be stimulated in order to achieve an acceptable Productivity Index, PI. Field A, Albian Carbonate in the Campos basin offshore Brazil falls into this challenging category. Effectively stimulating long horizontals has long been an industry challenge onshore and even more so in a deepwater environment. With the advent of Unconventionals in the US and Canada the ability to stimulate long horizontals has generated a great deal of focus and effort over the last few years. The high rate and multi-stage fracture stimulations done on these wells has resulted in the development of new industry techniques, notably using frac sleeves operated by dropping balls, and pumping down plugs and perforating guns to isolate and perforate each stage. This paper will review the concept selection process, detailed design work, testing, and implementation results of an extended reach horizontal well that utilizes onshore Unconventional ball drop technology adapted to a Deepwater setting to effectively stimulation a 2000 m long horizontal section. The well and stimulation treatment was considered an apparaisal effort such that if the production from the well is suitable it will open up the full Albian Carbonate for further development.

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