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Case Study: PEMEX Optimizes Production System for Large Gas Field in Northern Mexico
"The integrated operational database and automated surveillance capabilities have given us quick access to all production data, making it easier to manage this large asset"
Gilberto Sandoval Hernandez
Supervisor Production Engineer
PEMEX
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Volume management and analysis software enables Burgos field to automate surveillance across thousands of wells
Challenge
Automate production monitoring workflows for all wells in the field; synchronize data collection; and integrate daily and historical data into a single operational database.
Solution
Conduct a pilot study of 440 wells, using specialized production software:
- Avocet Volumes Manager (AVM)—for data capture and back allocation
- DECIDE! Data Hub—for data conditioning and workflow automation
- DECIDE! Desktop—for enhanced data analysis
- PIPESIM software—for rate estimation and regime setup
- DecisionPoint software—for visualization of KPIs, alarms, reports, and trends
Results
Minimized production losses, optimized current production, and improved decision making through automation and standardization of data-collection processes; and established quality control of operational data and data preservation.
Remove constraints to optimize production and minimize losses
The largest Petróleos Mexicanos (PEMEX) gas field located in northern Mexico, Activo Integral Burgos, experienced first-year production decline due to gas-loading backpressure, reduced permeability, and hydraulic fracture performance in the target formation. PEMEX decided to monitor the field and selected well candidates for workover. However, with approximately 2,000 wells and 95% of data captured manually, it was difficult to implement a continuous production- and performance-monitoring workflow or optimize and plan future operational resources.
The consultants were knowledgeable, but managing the data and the project was a challenge. Oilexco found the external models developed too conservative. Without the right proven reserve numbers, moving the project forward to development would be difficult.
Conduct a pilot project
Schlumberger Information Solutions (SIS) and the PEMEX operational production team conducted a pilot project in the Cuitlahuac sector of the Burgos gas field to synchronize data collected daily from 440 wells. SIS recommended a suite of production software, including Avocet Volumes Manager, DECIDE! Data Hub, DECIDE! Desktop, PIPESIM production system analysis software, and the DecisionPoint E&P Web-based solution for content and workflow delivery. These specialized tools were key to optimizing operational data collection, automation of workflows, and analysis and estimation of production.
Analyze, validate, and estimate production
The project team used both conventional and unconventional methods, such as nodal modeling, empirical equations, Turnerfs critical gas flow equation, decline curve analysis, and neural networks. They also validated and implemented a sequence of automated routines, designed to process data collected over the entire field.
The calculated gas rate was analyzed and validated at the well level using the available well test data and at the station level with the high-frequency data provided by SCADA systems. Daily production rates were computed using a more complex workflow that incorporated the empirical field equation, neural networks, proxy choke, pipe, and nodal models fed with operational data from each well. The critical gas rate to detect the liquid-loading problem was estimated using an automated workflow.
Establish production KPIs
The sophisticated production software enabled the team to establish the following KPIs, with easy access through a Web portal:
- identification of the gas rate for each well using operational data
- normalization of total production at the station level
- reports and alarms to identify operational events.
Ensure long-term operational success
The pilot project helped ensure long-term operational success of the Burgos field with improved monitoring, analysis, and forecasting capabilities. Identification and prevention of liquid-loading problems through automated monitoring and workflows with built-in alarms enabled timely decisions to avert problems and support well productivity. Well behavior issues can now be easily recognized using calculated rates at the well level and comparing their reconciled production to measurements at the gathering station level. Overall, PEMEX gained a more efficient means of surveillance and faster access to data.
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