DE-NT0006553

Goal
The goal of this project is to define, plan, and conduct a field trial of a methane hydrate production methodology whereby carbon dioxide (CO₂) molecules are exchanged in situ for the methane (CH₄) molecules within a hydrate structure, releasing the methane for production. The objective is to evaluate the viability of this hydrate production technique and to understand the implications of the process at a field scale.

Conceptual rendering of proposed CO₂ – CH₄ exchange methodology for the production of natural gas from hydrates.

Performer
ConocoPhillips Company, Houston TX and Anchorage AK
Japan Oil, Gas and Metals National Corporation (JOGMEC), Japan

Background
Globally and for the U.S., methane hydrates represent a potentially huge new source of the cleanest fossil fuel. A recent Minerals Management Service study estimated methane hydrate resources in the Gulf of Mexico at 21,000 trillion cubic feet (TCF), one hundred times the current U.S. proved reserves of natural gas. Hydrate accumulations off the Pacific and Atlantic coasts and on Alaska’s North Slope (ANS) hold additional potential. Yet this potential will remain untapped unless a technically and economically viable means of producing methane from hydrates is found.

Laboratory experiments conducted by ConocoPhillips and the University of Bergen have demonstrated the effectiveness of exchanging CO₂ for CH₄ in the hydrate structure; a process that releases the CH₄ molecules for production purposes. Key observations in those studies include the rapid rates of CO₂-CH₄ exchange in hydrates formed in porous media under a range of initial conditions; the efficiency of the carbon dioxide displacing the methane from the hydrate structure that approaches theoretical limits; and the preservation of measurable permeability in the porous media during hydrate formation and exchange. The most important observation is that the exchange process does not involve the release of free water to the pore system. Instead, the process appears to dissociate and re-form hydrate at very fast rates and on a micro-scale in such a manner that there is no free water formed or significant heat-of-reaction issues.

Under this project, ConocoPhillips plans to perform the first field trial of this promising, sustainable, methane hydrates production technology at a site on the Alaska North Slope (ANS).

Potential Impacts
The project will add significant data and knowledge to the body of hydrates science. Geologic and geophysical science used to locate and quantify methane hydrate deposits will be expanded as field trial sites are identified and prioritized. Hydrate reservoir modeling capabilities will be advanced as the algorithms needed to simulate the exchange process are developed. Experience in drilling and completions technology related specifically to gas hydrates will also be gained.

If this initial field trial is successful, the stage will be set for larger-scale, longer-term tests needed to advance viable production technologies for methane hydrates. The exchange technology could prove to be a critical tool for unlocking the methane hydrate resource potential in a manner that minimizes adverse environmental impacts such as water production and subsidence, while simultaneously providing a synergistic opportunity to sequester CO₂.

Accomplishments

• After measurement and compositional analysis, gas is flared at the Ignik Sikumi # 1 well site

  Completed injection of ~210,000 scf of mixed CO₂/N₂ gas into the hydrate bearing portion of the Ignik Sikumi #1 gas hydrate test well
• Addition of JOGMEC as a partner supporting project production testing efforts.
• Completion of laboratory experiments evaluating operational issues associated with the use of a CO₂/N₂ gas mixture as a hydrate reservoir injectant in place of liquid CO₂.
• Simulation of the temperature behavior of the intended production test injection fluid, allowing determination of required surface heating capacity for field operations.
• Completion of preliminary evaluation of data collected during 2011 drilling operations.
  • Logging results indicate four gas hydrate-bearing sand horizons in the well (in accordance with pre-drill predictions) including a 144 ft thick zone of clean, high-porosity sandstone with high gas hydrate saturation in the Sagavanirktok “Upper C”, which represents optimal pressure-temperature conditions for conducting the planned field trial.
  • The XPT tool successfully acquired data that will yield insight into ambient reservoir pressure and potential injectivity of various stratigraphic units.
  • The MDT tool was used primarily to conduct tests designed to measure formation breakdown pressures.
• Successful drilling, logging, instrumentation, completion and temporary suspension of the Ignik Sikumi #1 gas hydrate field trial well from an ice pad in the Prudhoe Bay operating Unit (PBU) on the North Slope of Alaska.
  • Operations included a comprehensive downhole data acquisition and site characterization program and installation of a fully-instrumented wellbore completion [PDF-schematic courtesy ConocoPhillips] available for additional field production testing.
  • Operations were completed without health, safety or environmental incident
  • Operations were conducted from a 500ft x 500 ft ice pad adjacent to the PBU L-Pad access road.
  • The surface was hole drilled, using water-based mud and logging-while-drilling (LWD) measurement, to a depth of 1,482 ft and then cased, cemented and pressure tested.
  • The remainder of the well was drilled (with LWD) to total depth of 2,597 ft using oil-based mud.
  • Wireline logs were obtained including: gamma-ray, resistivity, high resolution density, neutron porosity, oil-based mud imaging, combinable magnetic resonance, sonic scanner and borehole resistivity scanner.
  • Short duration tests were conducted using Schlumberger’s Express Pressure Tool (XPT) and Modular Formation Dynamic Tester (MDT).
  • Lower well completion included installation of an instrumented casing string with downhole temperature and pressure gauges and a continuous, fiber optic distributed temperature sensor.
  • Upper well completion included installation chemical injection and gas lift mandrels.
  • Freeze protection was implemented and the well temporarily suspended in preparation for anticipated re-entry during a subsequent winter drilling season.
• Acquisition of PBU Working Interest Owner approval for the performance of a two winter season, field test, as a tract operation, from an ice pad near the PBU L-Pad
• Completion of modeling efforts to evaluate the potential effects of field test operations (drilling and cementing) on the permafrost and hydrate zones of the field test site and surrounding conventional oil and gas operations
• Completion of modeling efforts to determine potential effects on the field test targeted hydrate zone from ongoing conventional oil and gas operations near the PBU L-Pad
• Completion of petrophysical studies providing supporting data for the planning of project field testing
• Completion of reservoir simulation for the production test, providing critical test design information
• Completion of laboratory experiments evaluating the effect of CO₂ hydrate formation on sample permeability
• Detailed evaluation, ranking and recommendation of project field sites on ANS

Current Status (March 2012)
The Ignik Sikumi gas hydrate field trial is underway! Track the progress.

The injection phase of the 2012 production related field trial initiated with wellbore perforation on February 15 and completed On February 28. During that period ~210,00 scf of mixed CO₂/N₂ gas was injected into the hydrate bearing Sagavanirtok "C" sandstone portion of the Ignik Sikumi #1 hydrate test well. During the flow back period injection rates gradually increased from ~11,000 scf/day to around 21,000 scf/day at completion of injection. Following injection operations the well was temporarily shut in while surface connections, metering and monitoring equipment were reconfigured. Flow back operations were initiated on March 4, are currently ongoing, and are expected to continue into April.

Collection of a full suite of data from wellbore instrumentation and the analysis of well flow back is being carried out throughout production testing operations. Following production testing, the current plan is to plug and abandon the Ignik Sikumi #1 well and restore the site. Field operations will be followed by review of the data collected and the initiation of extensive analysis of that data to determine the implications of test results.

Ignik Sikumi #1 field trial well site

Nordic-Calista Drilling Rig #3 on site at the Ignik Sikumi #1 well, Prudhoe Bay Unit, Alaska North Slope - photo courtesy ConocoPhillips

Project Start: October 1, 2008
Project End: June 30, 2013

Project Cost Information:
Site Selection (Phase 1) – DOE Contribution: $0, Cost Share Contribution: $288,378
Field Test Planning (Phase 2) – DOE Contribution: $0, Cost Share Contribution: $2,150,656
Well Drilling and Completion (Phase 3A) – DOE Contribution: $8,220,765, Cost Share Contribution: $1,627,154
Production Field Trial (Phase 3B) – DOE Contribution: $7,372,419, Cost Share Contribution: $9,284,776

Planned Total Funding: $27,366,792
DOE Contribution: $14,719,506 (fully obligated)
Cost Share Contribution: $12,647,286

Contact Information:
NETL – Richard Baker (Richard.Baker@netl.doe.gov or 304-285-4714)
ConocoPhillips – David Schoderbek (David.A.Schoderbek@conocophillips.com or 907-265-6010)
If you are unable to reach the above personnel, please contact the content manager.

Additional Information
In addition to the information provided here, a full listing of project related publications and presentations as well as a listing of funded students can be found in the Methane Hydrate Program Bibliography [PDF].

Semi-Annual Progress Report [PDF-1.79MB] - Period Ending 12-31-11

Semi-Annual Progress Report [PDF-25.2MB] - Period Ending 6-30-11

Semi-Annual Progress Report [PDF-2.00MB] - Period Ending 12-31-10

Semi-Annual Progress Report [PDF-4.25MB] - Period Ending 7-31-10

Quarterly Progress Report [PDF-69KB] - Period Ending 12-31-09

Experimental Hydrate Formation and Gas Production Scenarios Based on CO₂ Sequestration [PDF-144KB] - Proceedings of the 6th International Conference on Gas Hydrates (ICGH 2008)

Quarterly Progress Report [PDF-558KB] - Period Ending 9-30-09

Quarterly Progress Report [PDF-1.50MB] - Period Ending 6-30-09

Quarterly Progress Report [PDF-4.93MB] - Period Ending 3-31-09

Quarterly Progress Report [PDF-677KB] - Period Ending 12-31-08

Kickoff Meeting Presentation [PDF-891KB]