Trusted by Leading Energy Operators
From the Norwegian Continental Shelf to the Gulf Coast to multi-basin global portfolios — energy companies trust Seismic Swift AI to accelerate interpretation, automate compliance, and derisk subsurface decisions.
Operators across the energy sector
847
Surveys processed to date
12,000+
Pipeline jobs completed
99.97%
Actual platform uptime
4
Azure regions active
0
Data breaches — ever
Real results, real operators
Four detailed deployments across E&P, CCS, multi-basin governance, and geothermal exploration.
Norwegian Continental Shelf
6 weeks to 3 hours — across 12 surveys
“The audit chain alone justified the migration. Our compliance team no longer spends weeks reconstructing decision lineage for regulatory submissions. The science is faster and the paper trail is automatic.”
Challenge
A major NCS operator ran 12–15 3D seismic surveys per year across multi-asset portfolios. Manual horizon picking and fault interpretation consumed 4–6 weeks per survey, employed three to four dedicated geophysicists, and produced inconsistent quality across interpreters. Regulatory submissions to the Norwegian Petroleum Directorate required exhaustive decision documentation that consumed roughly 20 percent of total interpretation time.
- ✕4–6 weeks per survey — growing backlog of 8 queued surveys
- ✕Inconsistent interpretation quality across geophysicist teams
- ✕NPD regulatory documentation consuming 20% of project time
- ✕No quantified uncertainty on horizon picks or fault geometries
Solution
The operator deployed Seismic Swift AI across all NCS assets. The full ML pipeline — 3D U-Net denoising, DTW + GCN autotracking, Conv-VAE anomaly detection — processed surveys in under 10 minutes. Geophysicists shifted from manual picking to reviewing and approving AI predictions, concentrating effort on structurally uncertain zones. The SHA-256 audit chain produced NPD-ready documentation automatically.
- Full ML pipeline deployed across 4 asset teams simultaneously
- HITL review focused geophysicists on high-uncertainty predictions
- Automated audit chain replaced manual NPD decision documentation
- SEG-Y and OSDU R4 exports integrated with legacy data management
87%
Reduction in interpretation time
12
Surveys cleared from backlog in 90 days
94%
Horizon F1 vs manual baseline
100%
Regulatory audit trail coverage
Gulf Coast, 3 Injection Wells
Automated EPA Class VI evidence for 3 injection wells
“The mass balance module gave us quantitative confidence we could present to the EPA. Our environmental team now generates the 6-month monitoring report in an afternoon instead of a month. That is a structural change in how we operate.”
Challenge
A Gulf Coast CCS operator needed to demonstrate ongoing CO₂ containment across three Class VI injection wells to the EPA. Time-lapse seismic monitoring was scheduled at 6-month intervals, but the interpretation and reporting workflow was entirely manual — three weeks to process each vintage, two additional weeks for report preparation. The EPA required quantitative mass balance estimates with P10/P50/P90 uncertainty bounds.
- ✕3 weeks to process each time-lapse seismic vintage
- ✕2 additional weeks for EPA Class VI compliance report preparation
- ✕No automated mass balance or Monte Carlo uncertainty quantification
- ✕Manual plume boundary picking with no cross-vintage repeatability metrics
Solution
The operator deployed the Seismic Swift AI CCS monitoring suite. Gassmann fluid substitution linked amplitude changes to CO₂ saturation across all three wells. Monte Carlo uncertainty propagation delivered P10/P50/P90 mass estimates per monitoring epoch. NRMS repeatability analysis provided quantitative 4D QC metrics. EPA Class VI compliance reports were auto-generated with clause-referenced documentation and digital chain of custody.
- CCS monitoring pipeline with Gassmann-based plume mass balance
- P10/P50/P90 Monte Carlo uncertainty bounds per monitoring epoch
- NRMS repeatability QC for 4D vintage cross-comparison
- Automated EPA Class VI reports with full regulatory clause references
91%
Reduction in monitoring report time
96.9%
Mass balance conformance factor
< 3%
P50 deviation from metered injection volume
0
EPA revision requests across 4 reporting epochs
GoM + North Sea + Santos Basin
Centralized governance, region-pinned data sovereignty
“We could not find another platform that respected data residency across three jurisdictions and still gave us a single pane of glass. Seismic Swift AI solved a compliance problem we thought would take years to architect.”
Challenge
A multi-basin independent E&P operated assets in the US Gulf of Mexico, the UK/Norwegian North Sea, and Brazil's Santos Basin simultaneously. Data sovereignty rules in each jurisdiction prevented cross-border data movement. The operator needed unified interpretation tooling and governance reporting without compromising regulatory compliance in any region.
- ✕Data residency rules in 3 separate jurisdictions (US, EU, BR)
- ✕No single platform providing cross-basin governance without data egress
- ✕Inconsistent interpretation workflows and quality standards per region
- ✕Consolidated management reporting impossible without manual aggregation
Solution
Seismic Swift AI deployed dedicated Azure region instances in East US 2, UK South, and Brazil South. Each region processed and stored data within its legal boundary. A centralized governance dashboard aggregated job status, audit events, and compliance metrics across all regions without moving seismic data across borders. Tenant isolation enforced role-based access per asset team.
- Three Azure region deployments — data never crosses jurisdictions
- Centralized governance dashboard with real-time cross-basin job visibility
- Per-tenant RBAC with 25-permission role hierarchy per region
- Unified OSDU R4 metadata catalog across all three basins
3
Jurisdictions operating in compliance simultaneously
100%
Data residency compliance across all regions
60%
Reduction in cross-region governance overhead
1
Unified dashboard for all three basins
Western US — 2D Reprocessing
3 previously unmapped heat anomalies in 2D reprocessing
“We could not have justified seismic interpretation for our geothermal prospect at traditional consulting rates. Seismic Swift AI made seismic-guided exploration economically viable for a project of our scale, and found features we would otherwise have drilled past.”
Challenge
A geothermal developer in the western US had acquired archival 2D seismic lines over an enhanced geothermal system prospect. The team needed to identify fracture corridors, map reservoir compartments, and detect heat anomalies for stimulation targeting. Traditional geophysics consulting would have required six weeks of specialized interpretation at a cost exceeding the exploration budget for that phase.
- ✕Exploration budget insufficient for traditional consulting interpretation
- ✕No in-house seismic interpretation capability
- ✕Need to identify fracture corridors and heat anomalies from 2D data
- ✕Tight timeline to meet Phase 2 drilling permit application deadline
Solution
The developer reprocessed archival 2D lines through the Seismic Swift AI pipeline. 3D U-Net denoising improved signal quality on vintage data. Conv-VAE anomaly detection identified three thermal anomaly signatures in amplitude residuals not visible on conventional displays. DTW autotracking mapped structural horizons. Rock physics templates related elastic attributes to porosity proxies. GeoTIFF outputs integrated directly with the drilling permit GIS workflow.
- Full 2D reprocessing and structural interpretation in under 4 hours
- 3 thermal anomaly signatures identified by Conv-VAE anomaly detection
- Rock physics porosity proxies derived from elastic attributes
- GeoTIFF exports integrated directly with drilling permit GIS platform
3
Previously unmapped heat anomalies identified
95%
Cost reduction vs traditional consulting
< 4 hrs
Total interpretation turnaround
1st well
Hit predicted anomaly at target depth
What our customers say
Geophysicists, compliance directors, and engineering leaders on working with Seismic Swift AI.
“The quality gates caught an amplitude anomaly our team missed in manual QC. The automated flag saved us from a costly dry hole.”
“Migrating from legacy workstation software eliminated our per-seat licensing cost and our IT maintenance burden simultaneously. The ROI case was straightforward.”
“The OSDU R4 compatibility meant zero custom adapters to integrate with our existing data management environment. It just worked.”
“We process every geothermal prospect through the platform now. The cost per survey is a fraction of what we paid consultants, and the turnaround is measured in hours.”
“The SOC 2 audit chain was the deciding factor in our security review. Our CISO approved the platform in three weeks — that never happens.”
Standards and certifications
Independently validated compliance, security, and interoperability credentials.
Energy Tech 50
Top Energy AI Platform, 2025
SOC 2 Type II
AICPA Trust Service Criteria
OSDU Conformant
The Open Group OSDU R4 Forum
99.97% Uptime SLA
Trailing 12-month actuals
Ready to see it on your own data?
Schedule a 45-minute demo with a geophysicist from our team. We'll walk through the platform live using a survey representative of your basin.
No commitment required. Results on your own seismic data.