Smart Field: Is it Really Smart-Donkey Field Experience

This Green Field was commissioned and put on production few years ago and subsequently within a few months Miscible Hydrocarbon Gas injection was started on a Field scale. It is a modern Digital Oil Field having two artificial islands built to drill all its field development wells with advanced completions such as ICV, ICD and Permanent Downhole Gauges in all Oil Producer Wells with automated multi-phase flow metering (MPFM). This paper will describe the utilization of real-time data for better and efficient Field/Wells Monitoring along with quick and smart reservoir management decision-making & improved reservoir characterization. Real-time Dashboards (some of these were published last year, [1]) are utilized for robust screening of wells as per predefined rules and alerting Engineers for any wells, which are close to violating any of the Reservoir Management Guidelines, after QC and verification timely decisions, are made to avoid those violations. These Reservoir Management Guidelines for wells BHP & WHP are taken from Fluid Model (i.e. Equation of State) since the Field has a challenging considerable vertical compositional gradient for each of its reservoirs. The Guidelines are accordingly adjusted whenever a new verified information from PLT or PVT is available. Inter-well Gas Tracers Project implementation on Field scale is ongoing, where Tracers will be injected in all Gas Injection Wells/Strings to improve Reservoirs surveillance, Reservoirs understanding, Gas Injection Management, future wells locations and completion strategy etc. Real-time MPFM Flow Tests & Permanent Downhole Gauges Pressure data is utilized for Real-time Pressure Transient Analysis (PTA) and well shut in time for PBU is therefore optimized. Moreover, All Field/well Shut Down duration opportunities are also utilized for real-time Pressure Build-up (PBU) analysis & recording WHCIP & BHCIP surveys for Oil Producer wells and therefore considerable cost of running Memory gauges and intervention operations is saved. This paper shows examples of PTA data interpretation through real time data that improved decision-making and optimize the performance of each well. The benefits of implementing a digital oil field philosophy for improved decision making in order to maximize oil recovery in a challenging enhanced oil recovery offshore project is also discussed. Successful & Smart Reservoir Management is a result of collaborative and multiple discipline Team Work.

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Pushing 30 Years Multiple Brown Fields Limits Through Artificial Lift and Facilities Improvement

Ariffin¹,

Khalil²,

Razali³

et al. 2021

Day 1 Tue, March 23, 2021

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Most of the oil fields in Sarawak has already producing more than 30 years. When the fields are this old, the team is most certainly facing a lot of problems with aging equipment and facilities. Furthermore, the initial stage of platform installation was not designed to accommodate a large space for an artificial lift system. Most of these fields were designed with gas lift compressors, but because of the space limitation, the platforms can only accommodate a limited gas lift compressor capacity due to space constraints. Furthermore, in recent years, some of the fields just started with their secondary recovery i.e. water, gas injection where the fluid gradient became heavier due to GOR drop or water cut increases. With these limitations and issues, the team needs to be creative in order to prolong the fields’ life with various artificial lift. In order to push the limits, the team begins to improve gas lift distribution among gas lifted wells in the field. This is the cheapest option. Network model recommends the best distribution for each gas lifted wells. Gas lifted wells performance highly dependent on fluid weight, compressor pressure, and reservoir pressure. The change of these parameters will impact the production of these wells. Rigorous and prudent data acquisitions are important to predict performance. Some fields are equipped with pressure downhole gauges, wellhead pressure transmitters, and compressor pressure transmitters. The data collected is continuous and good enough to be used for analysis. Instead of depending on compressor capacity, a high-pressure gas well is a good option for gas lift supply. The issues are to find gas well with enough pressure and sustainability. Usually, this was done by sacrificing several barrels of oil to extract the gas. Electrical Submersible Pump (ESP) is a more expensive option compared to a gas lift method. The reason is most of these fields are not designed to accommodate ESP electricity and space requirements. Some equipment needs to be improved before ESP installation. Because of this, the team were considering new technology such as Thru Tubing Electrical Submersible Pump (TTESP) for a cheaper option. With the study and implementation as per above, the fields able to prolong its production until the end of Production Sharing Contract (PSC). This proactive approach has maintained the fields’ production with The paper seeks to present on the challenges, root cause analysis and the lessons learned from the subsequent improvement activities. The lessons learned will be applicable to oil fields with similar situations to further improve the fields’ production.

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Smart Field: Is it Really Smart-Donkey Field Experience

Cited by 3 publications

References 0 publications

Accelerometer-based Stroke Length Estimation of Sucker-Rod Pumping System in Smart Field

Accelerometer-based Stroke Length Estimation of Sucker-Rod Pumping System in Smart Field

Smart Reservoir Management with Real-Time Monitoring in an Offshore Carbonate Digital Oil Field under Miscible Gas Injection

Pushing 30 Years Multiple Brown Fields Limits Through Artificial Lift and Facilities Improvement

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