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Collaborating Authors
Shell Brasil Petroleo Ltda
Subsea Sampling Performed in the Deepwater BC-10 Field Offshore Brazil
Håheim, S. (Shell Brasil Petroleo Ltda) | Dutsch, D. (Shell Brasil Petroleo Ltda) | Pires, L. (Shell Brasil Petroleo Ltda) | Baima, J. (Shell Brasil Petroleo Ltda) | Galgoul, D. (Shell Brasil Petroleo Ltda) | Caldas, L. (Shell Brasil Petroleo Ltda)
Abstract The BC-10 O-North field is developed using water injection for pressure support. For reservoir management it is of substantial value to know the source of water observed in each well. Due to comingled wells and long flow lines, individual well sampling topsides is very difficult and give undesirable production deferment. To enable well fluid sampling from each individual producer, a subsea sampling access has been installed in Xmas tree. ROV deployed subsea multiphase sampling tools (SuMS Tools) have been developed, and a first subsea sampling campaign has been executed, retrieving samples from two individual wells in the BC-10 O-North field. The paper discuss the motivation for the sampling program, describe the sampling system, including Xmas tree modifications, sampling tool development and qualification, and describe the offshore execution of the first sampling campaign, with operational experiences and lessons learned. In addition to the technical content, this paper will also discuss the organizational and HSSE aspects of the sampling system and sampling process. The technology used consists of a SuMS panel installed on the subsea Xmas tree, which enable access to the production flow when connecting the ROV manipulated SuMS tool. The well is kept producing during the tool connection, sampling period and tool disconnection, enabling a sample to be taken with stable flow conditions. After retrieval to the intervention vessel, the ROV tool with the sample is transported to shore, where the sample bottle is disconnected, and brought to a laboratory. In the lab, the fluids are separated into gas oil and water before being shipped to the analyses laboratory in the US. The first sampling campaign was successful. The operation was performed efficiently, without any environmental or production impact, or damage to subsea hardware. The SuMS technology is innovative, and is a significant step forward in reservoir management of subsea wells in cases where individual well sampling at the topsides facility is not feasible or desirable. It is also presented as an alternative to the use of test separators for MPFM calibration, preventing production deferment.
- North America > United States (0.89)
- South America > Brazil (0.85)
- Asia > Middle East > Qatar > Arabian Gulf (0.45)
- South America > Brazil > Espírito Santo > South Atlantic Ocean > Campos Basin > Block BC-10 > Parque das Conchas Field (0.99)
- South America > Brazil > Campos Basin (0.99)
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field > Laffan Formation (0.99)
- Reservoir Description and Dynamics (1.00)
- Facilities Design, Construction and Operation > Offshore Facilities and Subsea Systems > Floating production systems (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Downhole and wellsite flow metering (0.90)
- Facilities Design, Construction and Operation > Offshore Facilities and Subsea Systems > Subsea production equipment (0.88)
MOBO ESP Interventions
Urban, A. (Shell Brasil Petroleo Ltda) | Boechat, N. (Shell Brasil Petroleo Ltda) | Haaheim, S. (Shell Brasil Petroleo Ltda) | Sleight, N. (Shell Brasil Petroleo Ltda) | Debacker, I. (Shell Brasil Petroleo Ltda) | Rivera, Robert (Shell Exploration and Production Co.)
Abstract The Shell operated Parque das Conchas fields of the Brazilian deepwater block BC-10 utilize ESPs as the sole artificial lift method. Unlike traditional in-well deployed ESP systems, the ten BC-10 ESPs are deployed inside relatively shallow – 100m - caissons distributed across three subsea gathering areas, or Artificial Lift Manifolds at water depths from 1650 to 1900m. The integrated caisson, ESP and inflow/outflow valving is deployed and retrieved as a single unit and hence derives the name of a Pump Module, or Modulo de Bomba in Portuguese, or MOBO for short. As ESPs have much shorter run lives compared to the approximate 25 year field life, the BC-10 subsea operations asset team is responsible for managing and executing the rig based ESP replacement intervention campaigns, or Mobo interventions. As of 2015, nine ESP replacements have been executed in four campaigns. This paper examines the diverse aspects associated with the ongoing efforts to maintain the artificial lift system of BC-10 before, during and after a rig intervention campaign. Topics covered include the ESP failure analysis, equipment sparing philosophy, equipment and tooling preparations, offshore execution, vendor relationships and overall project management. Finally, learnings obtained during the four years of near continuous preparation and execution of MOBO interventions are discussed along with some planned future improvements.
- South America > Brazil > Rio de Janeiro (0.28)
- Asia > Middle East > Qatar (0.28)
- South America > Brazil > Espírito Santo > South Atlantic Ocean (0.24)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Block BM-C-10 > Abalone Field (0.99)
- South America > Brazil > Campos Basin (0.99)
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field > Laffan Formation (0.99)
- South America > Brazil > Espírito Santo > South Atlantic Ocean > Campos Basin > Block BC-10 > Parque das Conchas Field (0.98)
Abstract The aim of this study is to present an analytical probabilistic approach using Monte Carlo Simulation method to estimate the minimum horizontal in situ stress magnitude from a single Leak-off test (LOT) acquired in highly deviated well in a sand interval inside the reservoir section, accounting for the uncertainties in some of the key input variables such as maximum horizontal in situ stress magnitude, and rock mechanic properties (Young Modulus, and Poisson’s Ratio). The major assumption used is that the Leak-off test (LOT) acquired was a representation of the fracture initiation pressure in the sand interval. A field case in a deep water turbidites oil field located offshore Brasil is presented to illustrate the application of this approach. The result of this study provides a full probabilistic density function (PDF) for the estimated minimum horizontal in situ stress magnitude. The result also indicated that the minimum horizontal in situ stress contrast between the reservoir and the overlying cap rock is relative small in any cases as expected in shallow and unconsolidated sediment environment. 1. INTRODUCTION Estimation of the minimum horizontal in situ stresses in the reservoir and cap rock is critical in onshore and offshore waterflood projects either if they will be executed at fracture or matrix conditions. Intentionally or unintentionally induced hydraulic fracture can breach the cap rock, eventually leading undesired fluids to the surface creating considerable environmental problems. As a result, interest in determination of minimum horizontal in situ stress has increased in recent years. Thus, it is extremely important to ensure that the injection can be maintained in a safe and effective manner. The minimum horizontal in situ stress can be determined by direct measurement via hydraulic fracturing, mini-fracs [1], and extended leakoff test (XLOT) [2]. However, it is quite often that only a limited leak-off test (LOT) is acquired during drilling operation, and used as a measure of the fracture initiation pressure (Pw), i.e., not a valid measure of the minimum horizontal in situ stress. The present work is aimed to use a probabilistic approach to estimate this in situ stress magnitude, hence, providing a critical input into the operational envelope for the water injection in the field under study.
Espirito Santo: Operational Feedback on the Use of Steel Risers on a Turret Moored FPSO
Newport, Andrew (SBM Offshore) | Haheim, Svein (Shell Brasil Petroleo Ltda) | Martineau, Eric (SBM Offshore)
Abstract The FPSO Espirito Santo, located offshore Brazil in the Parque das Conchas (BC-10) field, is the world's first turret moored FPSO to use steel risers for fluid transfer. The FPSO is moored in a water depth of 1, 780 meters, and the internal turret incorporates a total of 21 riser and umbilical slots. The steel risers, which are in a Lazy Wave configuration, were pulled into the turret through inclined I-tubes. Clamps at the top of the I-tubes retain the risers, thus transferring axial loads from the risers to the turret. A clamp casting welded at the bottom of the I-tubes houses a stopper arrangement designed to transfer shear forces and moments from the risers to the turret. The FPSO began oil production in July 2009, and now has over 4 year's optional experience. During this period, inspection of the riser system and the associated flex-joint has confirmed the integrity of the design, giving further confidence in the use of steel risers in turret moored systems. This paper summarizes the basis for selecting steel risers for the development, how the risers and umbilicals interface with the turret, and the impact of the riser choice on the turret design. The in-service inspection of the riser system is described and the results reported.
- South America > Brazil (0.68)
- North America > United States > Texas (0.46)
- Europe (0.46)
- South America > Brazil > Espírito Santo > South Atlantic Ocean > Campos Basin > Block BC-10 > Parque das Conchas Field (0.99)
- South America > Brazil > Campos Basin (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Block BC-10 > Argonauta Field (0.94)
Abstract: The aim of this study is to investigate deterministic and probabilistic slip tendency to assess the reactivation potential of a pair of pre-existing normal faults present in a deep water turbidite oil field, where water is planned to be injected at in-situ virgin reservoir condition. The methodology used is fully analytical, and has served to estimate the critical pressure perturbation that induce shear slip along the pre-existing faults which are still under a normal faulting stress regime, therefore, helping to define the operational envelope during the water injection phase. This piece of work also considers the rebound of stresses upon injection using the finding by Santarelli et al., 1998, where basically none or little increment of the minimum horizontal stress was observed during injection. A Monte Carlo Simulation approach has been used for the probabilistic analysis, accounting for the uncertainties associated with some of the input variables. The use of the valuable pole of the stress circle concept also helped to validate some of the results to some extent.
- Geology > Structural Geology > Fault (1.00)
- Geology > Sedimentary Geology > Depositional Environment > Marine Environment > Deep Water Marine Environment (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.62)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Block BC-10 > Argonauta Field (0.99)
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field > Laffan Formation (0.99)