Unlocking Idle Production in an Offshore Sandstone Oil Field With Gas Hydrate Issues

2021 ◽  
Author(s):  
Babalola Daramola
Keyword(s):  
Gas Hydrate ◽  
Oil Production ◽  
Oil Field ◽  
Third Party ◽  
Flow Assurance ◽  
Well Testing ◽  
Production Wells ◽  
Oil Flow ◽  
Offshore Oil ◽  
Production Losses

Abstract This publication presents how an oil asset unlocked idle production after numerous production upsets and a gas hydrate blockage. It also uses economics to justify facilities enhancement projects for flow assurance. Field F is an offshore oil field with eight subsea wells tied back to a third party FPSO vessel. Field F was shut down for turnaround maintenance in 2015. After the field was brought back online, one of the production wells (F5) failed to flow. An evaluation of the reservoir, well, and facilities data suggested that there was a gas hydrate blockage in the subsea pipeline between the well head and the FPSO vessel. A subsea intervention vessel was then hired to execute a pipeline clean-out operation, which removed the gas hydrate, and restored F5 well oil production. To minimise oil production losses due to flow assurance issues, the asset team evaluated the viability of installing a test pipeline and a second methanol umbilical as facilities enhancement projects. The pipeline clean-out operation delivered 5400 barrels of oil per day production to the asset. The feasibility study suggested that installing a second methanol umbilical and a test pipeline are economically attractive. It is recommended that the new methanol umbilical is installed to guarantee oil flow from F5 and future infill production wells. The test pipeline can be used to clean up new wells, to induce low pressure wells, and for well testing, well sampling, water salinity evaluation, tracer evaluation, and production optimisation. This paper presents production upset diagnosis and remediation steps actioned in a producing oil field, and aids the justification of methanol umbilical capacity upgrade and test pipeline installations as facilities enhancement projects. It also indicates that gas hydrate blockage can be prevented by providing adequate methanol umbilical capacity for timely dosing of oil production wells.

scholarly journals Offshore oil production planning optimization: An MINLP model considering well operation and flow assurance

2020 ◽  
Vol 133 ◽  
pp. 106674
Author(s):  
Xiaoyong Gao ◽  
Yi Xie ◽  
Shuqi Wang ◽  
Mingyang Wu ◽  
Yuhong Wang ◽  
...  
Keyword(s):  
Production Planning ◽  
Oil Production ◽  
Flow Assurance ◽  
Planning Optimization ◽  
Offshore Oil Production ◽  
Minlp Model ◽  
Offshore Oil

scholarly journals Flow Assurance

2015 ◽  
Vol 137 (03) ◽  
pp. S13-S15
Author(s):  
Phaneendra Kondapi
Keyword(s):  
Cash Flow ◽  
Deep Water ◽  
Oil And Gas ◽  
Electric Heating ◽  
Oil Field ◽  
Flow Assurance ◽  
Efficient Management ◽  
Oil Flow ◽  
Exploration And Production ◽  
Cost Efficient

This article explores various aspects of flow assurance in subsea developments. Flow assurance is an understanding of multiphase flow fluid dynamics and analyses, an ability to identify flow-related problems using state-of-the-art prediction tools, and the knowledge to develop solutions that eliminate, mitigate or remediate flow-related issues encountered in subsea systems. Flow assurance is reliable, safe and cost-efficient management of hydrocarbons from reservoir to export without any flow-related issues over the life cycle of the oil field. Subsea developments continue to escalate in quantity and complexity as the exploration and production companies ramp up exploration of deep-water and ultra-deep-water reservoirs with complex formations in harsh environments with increased challenges. Some of the technologies under thermal solutions are thermal insulation, direct electric heating and electrically-heated pipe-in-pipe. Oil and gas companies generate revenue from the oil produced. If the oil flow stops, their revenue stops. The more it stops the more they lose cash. Hence it can be termed as cash flow assurance. With fluctuating oil prices and unpredictable production issues, engaging flow assurance at every stage starting with the early phase ensures uninterrupted transportation of reservoir fluid from pore to process facilities in a safe manner and insures cash flow.

Durability Review of Elastomers for Severe Fluid Duties

2003 ◽  
Vol 76 (3) ◽  
pp. 719-746 ◽  
Author(s):  
Robert P. Campion
Keyword(s):  
Personal Experience ◽  
Residual Life ◽  
Oil Production ◽  
Oil Field ◽  
Offshore Oil Production ◽  
Offshore Oil

Abstract Durability aspects of elastomers when exposed to fluids under severe conditions for Offshore Oil Production and other applications have been reviewed. Examples are provided of situations where estimations of residual life might be made, and of others where different considerations might be the overriding factors. The approach has been to extend previously-presented overviews focused on the use of elastomers in the hostile conditions of the oil field industry, and made largely from personal experience, to include some work of others with reference to other application areas as well.

scholarly journals Simple stationary filtering flows of incompressible non-newtonian oil in a homogeneous formation according to a general nonlinear law

2021 ◽  
Vol 1 ◽  
pp. 39-45
Author(s):  
Maral Gasan kyzy ALIEVA ◽  
◽  
Niyaz Gadym ogly VALIEV ◽  
Keyword(s):  
Fluid Flow ◽  
Oil Field ◽  
Practical Significance ◽  
Scientific Article ◽  
Filtration Flow ◽  
Plane Parallel ◽  
Production Wells ◽  
Oil Flow ◽  
Simple Filtration ◽  
Simple Flows

Three stationary hydrodynamic theoretical problems are solved, in which filtrations obey only the General nonlinear law. Simple flows occur in tasks: plane-parallel, plane-radial, and hemispherical-radial. All derived formulas – oil flow rate, filtration rate, pressure gradient, etc. – should be used to solve various practical problems of the development of these deposits and even when drawing up a project for the development of such deposits. It should be noted that a plane-parallel simple filtration flow of oil originates from a strip-like reservoir to a straight gallery. In addition, such a simple filtration fluid flow also occurs when the oil field under development has several parallel rectilinear rows of production production wells and, in some cases, there may be rows of injection water wells in the reservoir. In oil-bearing areas between parallel adjacent rows, oil filtration is also plane-parallel. Hence, the practical significance of solving the first problem of a plane-parallel oil flow in this scientific article becomes clear. Planar-radial simple filtration flow of oil originates from a circular horizontal formation to a central production well. In addition, such a simple filtration fluid flow also occurs when a strip-like oil field being developed has several (usually three or four) parallel straight rows of production production wells. In the drainage zones of these wells, a simple flat-radial filtration flow also occurs. From the foregoing, the practical significance of a radial plane oil flow becomes clear. Hemispherical – a radial simple filtration flow of oil originates from a hemispherical reservoir to a central well, barely penetrated by the reservoir by its hemispherical concave bottom. By analyzing these calculation formulas, you can identify the specific features of the development of deposits, develop and implement measures to eliminate undesirable phenomena.

scholarly journals Status Quo of a CO2-Assisted Steam-Flooding Pilot Test in China

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-13
Author(s):  
Zongyao Qi ◽  
Tong Liu ◽  
Changfeng Xi ◽  
Yunjun Zhang ◽  
Dehuang Shen ◽  
...  
Keyword(s):  
Field Test ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Oil Production ◽  
Oil Field ◽  
Drainage Pattern ◽  
Steam Flooding ◽  
Production Wells ◽  
Water Cut ◽  
Production Dynamics

It is challenging to enhance heavy oil recovery in the late stages of steam flooding. This challenge is due to reduced residual oil saturation, high steam-oil ratio, and lower profitability. A field test of the CO2-assisted steam flooding technique was carried out in the steam-flooded heavy oil reservoir in the J6 block of the Xinjiang oil field (China). In the field test, a positive response to the CO2-assisted steam flooding treatment was observed, including a gradually increasing heavy oil production, an increase in the formation pressure, and a decrease in the water cut. The production wells in the test area mainly exhibited four types of production dynamics, and some of the production wells exhibited production dynamics that were completely different from those during steam flooding. After being flooded via CO2-assisted steam flooding, these wells exhibited a gravity drainage pattern without steam channeling issues, and hence, they yielded stable oil production. In addition, emulsified oil and CO2 foam were produced from the production well, which agreed well with the results of laboratory-scale tests. The reservoir-simulation-based prediction for the test reservoir shows that the CO2-assisted steam flooding technique can reduce the steam-oil ratio from 12 m3 (CWE)/t to 6 m3 (CWE)/t and can yield a final recovery factor of 70%.

Optimising Flow Assurance Strategies in an Offshore Sandstone Oil Field with Gas Hydrate Issues

2018 ◽  
Author(s):  
Babalola Daramola ◽  
Chidubem Martins Alinnor
Keyword(s):  
Gas Hydrate ◽  
Oil Field ◽  
Flow Assurance

Lessons Learned from Optimising Sand Control and Management Strategies in a Low Permeability Sandstone Oil Field

2021 ◽  
Author(s):  
Babalola Daramola ◽  
Chidubem Martins Alinnor
Keyword(s):  
Management Strategies ◽  
Oil Production ◽  
Lessons Learned ◽  
Oil Field ◽  
Sand Production ◽  
Injection Wells ◽  
Well Integrity ◽  
Sand Control ◽  
Production Wells ◽  
Control And Management

Abstract This paper presents the lessons learned from optimising the sand control and management strategies of an oil field (Field E) after multiple sanding events and well failures. It presents how the old sand control solution was selected, the failure root causes, and the remediation options considered. The new sand control method, and the performance of two re-drilled wells after two years of production are also presented. Field E is a sandstone field with oil and gas-cap gas at initial conditions, and was initially developed with 5 production wells, 2 water injection wells, and 2 gas injection wells. The development wells were drilled from an offshore platform, and completed with stand-alone screens (SAS) in 2013. Oil production commenced in late 2013, and within three years, sand production was observed, and 4 of the 5 oil production wells had failed. The 4 wells were re-drilled in 2017, and the sand control strategy was changed from stand-alone screens to frac-packs. Key lessons learned include completing sand strength studies pre-development, avoiding off-the-shelf sand control solutions, and completing sand control design studies based on service contractor capability, fines control, oil production rates, and sand control as key selection factors. Nearby wells should be shut in during infill drilling operations to avoid short circuits, drilling mud losses, completions damage, and well integrity failures. It is recommended that the bean up procedures of wells with sanding events are changed to slow bean up to preserve well integrity, oil production, and cash revenues. The asset team should consider installing sliding sleeves or inflow control devices for zonal testing and to choke or close sand production zones if needed. The asset team should also consider installing a test pipeline and a test separator to allocate sand production volumes from each well, clean up new wells, sample the wells for water salinity measurements, and other benefits.

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