Africa (Sub-Sahara) Aminex Petroleum Egypt (APE), a subsidiary of UK-based Aminex, discovered oil at its South Malak-2 (SM2) well on the West Esh el Mellaha-2 concession in Egypt. Tests showed flow rates of approximately 430 B/D of 40 API gravity crude oil. Based on the findings at SM2, a full field development program will be presented to the Egyptian authorities and the joint venture partners before commercial development. APE is the operator of the license with partner Groundstar Resources. Foxtrot International discovered oil and gas at its Marlin North-1 well in Block CI-27, offshore Cote d'Ivoire. A 22-m perforated section of a gas-bearing column in a Turonian interval flowed at a stabilized rate of 25 MMcf/D of gas and 150 B/D of condensate through a 46/64-in.
Harstad is not the end of the world but you can see it from there, a real frontier area. From this area above the polar circle exploration and development has been lead in the Norwegian and the Barents seas. Exploration wells are being drilled in the now opened former disputed areas, was it worth the fuss? "Technology forum about the Arctic in the Arctic" has always been the slogan of the SPE Northern Norway Workshop. In March 2019, this two-day biannual workshop will raise the stakes, broaden the scope, and showcase all the latest success in the region.
Olalotiti-Lawal, Feyi (Texas A&M University) | Onishi, Tsubasa (Texas A&M University ) | Kim, Hyunmin (Texas A&M University ) | Datta-Gupta, Akhil (Texas A&M University ) | Fujita, Yusuke (JX Nippon Oil & Gas Exploration Corporation) | Hagiwara, Kenji (JX Nippon Oil & Gas Exploration Corporation)
We present a simulation study of a mature reservoir for carbon dioxide (CO2) enhanced-oil-recovery (EOR) development. This project is currently recognized as the world’s largest project using post-combustion CO2 from power-generation flue gases. With a fluvial formation geology and sharp hydraulic-conductivity contrasts, this is a challenging and novel application of CO2 EOR. The objective of this study is to obtain a reliable predictive reservoir model by integrating multidecadal production data at different temporal resolutions into the available geologic model. This will be useful for understanding flow units along with heterogeneity features and their effect on subsurface flow mechanisms, to guide the optimization of the injection scheme and maximize CO2 sweep and oil recovery from the reservoir.
Our strategy consists of a hierarchical approach for geologic-model calibration incorporating available pressure and multiphase production data. The model calibration is performed using regional multipliers, and the regions are defined using a novel adjacency-based transform accounting for the underlying geologic heterogeneity. The genetic algorithm (GA) is first used to match 70-year pressure and cumulative production by adjusting pore volume (PV) and aquifer strength. Water-injection data for reservoir pressurization before CO2 injection is then integrated into the model to calibrate the formation permeability. The fine-scale permeability distribution consisting of more than 7 million cells is reparameterized using a set of linear-basis functions defined by a spectral decomposition of the grid-connectivity matrix (Laplacian grid). The parameterization represents the permeability distribution using a few basis-function coefficients that are then updated during history matching. This leads to an efficient and robust work flow for field-scale history matching.
The history-matched model provided important information about reservoir volumes, flow zones, and aquifer support that led to additional insight compared with previous geological and simulation studies. The history-matched field-scale model is used to define and initialize a detailed fine-scale model for a CO2 pilot area that will be used to study the effect of fine-scale heterogeneity on CO2 sweep and oil recovery. The uniqueness of this work is the application of a novel geologic-model parameterization and history-matching work flow for modeling of a mature oil field with decades of production history, and which is currently being developed with CO2 EOR.
Hou, Jing (Research Institute of CNOOC) | Wei, Weirong (Shenzhen Branch of CNOOC) | Liang, Yu (Shenzhen Branch of CNOOC) | Sun, Qiwei (Shenzhen Branch of CNOOC) | Chang, Shijun (Shenzhen Branch of CNOOC) | Gao, Yuan (Shenzhen COOEC Subsea Technology Co.)
This paper is to summarize the challenges for Liwan gas field export pipeline during the rock dumping engineering design and fall pipe rock dumping execution, corresponding measures and acceptable criteria. The success of the project provides excellent experience for resolving pipeline free span and subsea infrastructure protection issues, which would be beneficial and used as reference for future deep water oil and gas development.
The floating production, storage, and offloading (FPSO) facility Espirito Santo, located offshore Brazil in the Parque das Conchas (BC-10) field, is the world's first turret-moored FPSO facility to use steel risers for fluid transfer. The FPSO facility is moored in a water depth of 1780 m, and the internal turret incorporates a total of 21 riser and umbilical slots. The steel risers, which are in a lazywave 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 facility began oil production in July 2009, and now has more than 5 years of operational 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.
BP have worked with Wood Group Kenny (WGK) since 2010 to design a robust riser system which will service a harsh-environment FPSO for the next 25 years, in some of the most hostile environmental conditions in the world. Quad204 is located approximately 130 km west of Shetland in 400 m water depth. In order to deliver hardware which would match the expected facility uptime, and to provide a best-in-class toolbox for integrity management of the riser system during operation, a design program was set up with heavy emphasis on learning from operational experience in the region, and incorporating more onerous Metocean conditions for the new production platform, the turret moored Glen Lyon FPSO, which is significantly bigger than her predecessor, Schiehallion. A detailed review of BP's West of Shetland (WoS) and Northern North Sea (NNS) operational experience, including previous riser system designs and integrity concerns was carried out in 2010-11. This led to the specification for the Quad204 dynamic riser system which incorporated several unique features to address the location and platform constraints, as well as the restricted construction season. These particular features were identified as value-adding early in the process, and built into the specification, and subsequent detailed design process, to enhance the system integrity over a lifetime operating in this environment: additional layers of tensile armour to extend riser corrosion fatigue life; double outer sheaths to obviate the consequences of installation damage; autonomous annulus monitoring; enhanced turret/end-fitting venting capacity; turret motion response monitoring; riser I-tube inspection facilities and pipe specimen retention. An extensive program of inspection and dissection of recovered Schiehallion hardware was also carried out to confirm the integrity of the retained brownfield infrastructure. The design, qualification and manufacture of the biggest bend stiffener produced by the supplier transpired to be a significant risk for the project and the program to address this is described herein. The final riser system - a combination of bespoke hardware and supporting integrity management tools - is believed to be state of the art for harsh-weather floating production systems.
Glass plugs technology was initially installed on Skarv field by BP. In partnership with technology provider, the new concept of completion barrier plugs was dynamically implemented. Its purpose was to close the lower formations of reservoir until the time the well was ready to proceed with production from those zones. The early years showed that even if this technology is forward-looking, the risk of failure and intervention still exists.
According to the operator’s data three out of ten wells demanded the emergency glass plug opening and in the rest of cases the small complications occurred. Emergency breaking of the glass plug involves renting a unit and running the wireline with a tractor. It is an additional cost that can be optimized by understanding the challenge and proposing the accurate approach.
Base of this research is the analysis of failure cases, activities that have been taken up by an operator and final outcomes from the operations. It is supplemented by the analysis of the optimal intervention concept according to economic calculations and market availability. The aim of the research is to transfer the knowledge acquired from failure cases into the recommendations for running such interventions and provide criteria to final assessment of available solutions.
Aker Solutions has secured a framework contract to provide engineering, modifications, and maintenance services for BP-operated oil and gas fields offshore Norway. The contract, valued at a maximum of USD 292 million, has a period of up to 2 years, with options to extend the work by as many as 4 years. The agreement is for work on the Ula, Tambar, Hod, Skarv, and Valhall fields. The scope of work includes studies, maintenance, and modification project work, as well as preparation work for offshore decommissioning.
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.