From the Utility Management edition of November 10, 2026
UAMPS and Basin Electric win OATI AI use-case challenge for an agent that chooses book-out vs physical flow, buys transmission and builds e-Tags
OATI (Open Access Technology International) with Utah Associated Municipal Power Systems (UAMPS) and Basin Electric Power Cooperative · Public power joint action agency and G&T electric cooperative: wholesale scheduling and transmission · Intermountain West and Upper Midwest, United States
- Publisher
- OATI news
- Original publication
- 2026-11-10
- Source retrieved
- 2026-11-11
What happened
At OATI Energy Conference 2026, UAMPS (wholesale supplier to 50 community-owned systems in seven states) and Basin Electric (G&T owned by 138 member co-ops in nine states) jointly won an AI use-case workshop with an agent concept: decide whether a transaction should be a financial book-out or physical flow under current market conditions, find and buy transmission on the right path, build the e-Tag, and pre-build an alternative route and tag in case of curtailment. OATI will develop it with schedulers and traders on its OASIS and e-Tagging systems; each organisation gets a year of complimentary service. OATI's guidance lists constraints that make pilots 'rise or stall': NERC CIP, operator trust and data availability.
Why it matters
A concrete agentic-AI use case owned by a municipal joint action agency and a co-op, areas thin in recent editions. It is a concept, not a deployment, but shows where public power sees agent value: frequent, time-pressured, data-heavy scheduling decisions.
Evidence and measured results
Vendor announcement; no prototype, accuracy or time-saving data. Winning idea will be developed; complimentary service creates a commercial relationship.
Limitations and uncertainty
Concept stage; vendor marketing; no independent assessment; results may not apply to distribution-only municipal utilities.
Put this evidence to work
Lighthouse Advisory interpretation, grounded in this source. Enriched 2026-11-10; this does not change the original publication date. Each role follows the same checklist so takeaways compare across sources.
Sales
Role takeaway
- Customer problem
- Schedulers repeatedly connect market, transmission and tagging steps under deadline pressure, and redo them when curtailments hit.
- Stakeholders
- Scheduling and trading manager
- Compliance (NERC CIP) lead
- Member utility representatives
- IT/OT security
- Discovery questions
- How many book-out vs physical-flow decisions are made per day?
- How often do curtailments force re-tagging?
- Which actions could an agent take without human approval?
- What data feeds are reliable enough for automation?
- Value hypothesis
- An agent with bounded authority could reduce time spent assembling transmission reservations and tags, measured in shadow mode before use.
- Potential engagement
- Use-case scoping and shadow-mode evaluation design for an agency's scheduling workflow.
- Unsupported claims
- That the agent exists or works today
- Any time or cost savings
- That it meets NERC CIP requirements
Pre-sales engineering
Role takeaway
- Fit
- Joint action agencies, G&T co-ops and municipal utilities that schedule wholesale power and buy transmission.
- Architecture and integration
- Agent layered on OASIS, transmission purchase and e-Tag systems with action logging and approval workflow.
- Prerequisites
- Documented decision rules
- Market and ATC data feeds
- Approval thresholds
- Constraints
- NERC CIP scope
- Market rules on tagging deadlines
- Vendor-platform dependency
- Security
- Separate agent credentials, least privilege for purchases, immutable logs and operator override.
- Proof of value
- Shadow-mode agreement with schedulers
- Time-to-tag comparison
- Curtailment fallback test
Delivery
Role takeaway
- Work
- Map current decisions, define authority limits, run shadow mode, then stage limited authority.
- Dependencies
- Vendor development
- Scheduler time
- Compliance review
- Ownership
- Scheduling and trading manager.
- Skills and adoption
- Schedulers trained to supervise and override agent actions.
- Governance checkpoints
- NERC CIP applicability review
- Authority-limit approval
- Go-live decision on shadow results
- Acceptance criteria
- Agreed agreement rate with human decisions
- All tags submitted before deadlines in test
- Zero unauthorised transactions
- Risks
- Operator distrust
- Bad data driving purchases
- Lock-in after free year
Implementation considerations
Lighthouse Advisory interpretation across the operating dimensions a public-sector buyer must settle before this evidence becomes a design. Each note answers the question under its heading for this specific source.
Architecture and integration
What must connect, and where does the AI sit in the workflow?
Agent operates on existing OASIS reservation and e-Tag workflows; actions include purchasing transmission, which implies transactional authority and audit requirements.
Governance
Who approves, reviews and stays accountable for outcomes?
An agent that buys transmission and submits tags needs explicit authority limits, human approval thresholds and market-compliance review.
Security and privacy
What data, permissions and controls need testing?
Bulk electric system scheduling sits near NERC CIP scope; agent credentials and actions require strong access control and logging.
Accessibility and workforce
Who is affected, and what skills or accommodations follow?
Schedulers and traders shape the agent; their expertise and trust are prerequisites.
Procurement
What should contracts, pricing and exit terms secure?
Free first-year service may lead to lock-in; agencies should define exit and data-ownership terms.
Operating model
Which teams own the service once it runs?
Shifts schedulers from executing steps to supervising an agent and handling exceptions such as curtailments.
Publication history
- 2026-11-10Utility Management · Issue 126 resources
Stable resource ID: oati-uamps-basin-electric-ai-agent-etag-transmission-challenge-2026