Exploration and Production Technologies

Improved Miscible Nitrogen Flood Performance Utilizing Advanced Reservoir Characterization and Horizontal Laterals in a Class I Reservoir-East Binger

DE-FC26-00BC15121

Project Goal
The objectives of the project are to demonstrate use of nitrogen as a widely available, cost-effective and environmentally superior injectant for miscible floods and to demonstrate the effectiveness of horizontal wellbores in reducing gas breakthrough and cycling.

Performers
Binger Operations 
Oklahoma City, OK

Nielson & Associates Inc. 
Cody, WY

Canyon Oil & Gas 
Wichita, KS

International Reservoir Technologies, Inc.
Lakewood, CO

Project Results
Through the process of evaluating the benefits of horizontal wells in this setting, a greater understanding of the reservoir flow mechanisms has been obtained, allowing further development and improved recovery for the field. This geologic and reservoir setting, combined with the recovery mechanism employed, has proven to be more appropriate for vertical well development.

Based on results achieved, additional drilling beyond the scope of the original project has been completed. Project development work has added 200-300 barrels of oil per day to field production, roughly doubling production in the project area.

Binger Operations has completed the following:

  • Drilled and completed three horizontal and seven vertical wells.
  • Converted five wells to injection service.
  • Completed modeling and fluid flow characterization work to identify critical fluid flow mechanisms.
  • Evaluated over 200 gas samples to monitor gas cycling and the effects of producer-to-injector conversions.

Benefits
Three horizontal wells have been drilled into the Pennsylvanian Hoxbar formation of the Eastern Anadarko Basin, where previously only one such well had been drilled. Drilling difficulties were encountered and overcome. Although these technologies were not proven to be the most cost-effective for this field-in large part due to the recovery mechanism employed-they very likely will be the most cost-effective drilling technique in similar reservoirs with different recovery mechanisms. The lessons learned here will thus benefit industry, the State, and the general public through improved oil recovery.

In addition to the development of horizontal drilling practices in this area, the State and general public also will benefit from the improved understanding of the nitrogen flood underway in the East Binger Unit. With this improved understanding, the operator will apply additional knowledge to increase economic oil recovery from the field, providing monetary benefit to the State and local tax bases. The public also benefits through improvement in the labor market.

Background
The East Binger (Marchand) Unit has been under miscible gas flood since unitization in 1977, first with flue gas and then with nitrogen. As with any flood, the injected fluid finds its way to producing wells (cycling) and must be handled. This flood was no different, except that the degree of cycling was high for the level of recovery. Initial review indicated the injected nitrogen was overriding the oil (gravity segregation) and moving to producers without mixing with and swelling the oil. It was believed that by placing horizontal producing wells at the base of the reservoir, miscibility could be improved and cycling reduced.

Project Summary
Project researchers have:

  • Improved understanding of flow mechanisms in the Pennsylvanian Hoxbar formation of the Eastern Anadarko Basin.
  • Successfully drilled and completed three horizontal wells in the Pennsylvanian Hoxbar formation of the Eastern Anadarko Basin, in which only one horizontal well had previously been drilled.
  • Tested the viability of horizontal wells in a tight sandstone formation under nitrogen miscible flood.

Through the process of implementing the project, it was determined that the initial assumptions of flow mechanisms in the reservoir were largely incorrect. Directional flow driven by fracturing-not gravity segregation-appears to be the primary flow mechanism. With this improved understanding, methods to improve recovery are being implemented.

Horizontal well development was tested and found to be economically inferior to vertical well development. Based on the newly identified reservoir flow mechanisms, the optimal pattern configuration is a line drive, with lines of injectors and producers oriented in line with the direction of natural and hydraulic fracturing. As such, horizontal wells should be drilled along this line. Due to the low rock quality, all wells-including horizontal wells-must be fracture-stimulated to be productive. The optimal flood pattern configuration, combined with the need to fracture-stimulate, makes vertical infill well development economically superior to horizontal infill well development.

Current Status (June 2006)
This project was essentially complete at the end of 2005. Researchers are in the final stages of monitoring results of the work completed. The project initially was planned for completion in April 2005, but no-cost extensions in Budget Periods 1 (+8 months) and 2 (6 months) extended the final completion date to June 30, 2006.

Project Start: April 11, 2000
Project End: June 30, 2006

Anticipated DOE Contribution: $ 3,157,349
Performer Contribution: $ 10,213,824 (77% of total)

Contact Information
NETL - Chandra Nautiyal (chandra.nautiyal@netl.doe.gov or 918-699-2021) 
Binger - Joe Sinner (joe@ironcreekenergygroup.com or 307-587-2445)

Publications
Technical reports are available on the project web site: www.eastbingerunit.com.

This illustration shows the performance of the DOE Project Pilot Area. Implementation of the project began in mid-2002 with the conversion to injection (CTI) of well 57-1. New production wells and additional CTIs followed. Pilot area oil production has increased 83 percent, over 200 barrels per day, from the projected base decline. Perhaps more important, nitrogen recycle (nitrogen production divided by injection) has decreased from 70 percent to 40 percent.


The pair of graphs shows a comparison of the performance of new vertical wells with the performance of new horizontal wells. With horizontal wells costing roughly twice the cost of vertical wells, they are not economically justified in this geologic setting with the recovery mechanism employed.

Air separation and compression facility for N2 injection plant at East Binger Unit, Caddo County, OK

Air separation plant, East Binger Unit, Caddo County, OK.

 
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