Field Development Plan — Big Foot
Summary
A dry-tree tension-leg development with reported first oil in November 2018.
Historical source snapshot, not a current operating-status assertion or a sanctioned engineering design. Missing inputs are preserved as unknown.
Revision history
| Revision | Date | What changed and why |
|---|---|---|
| Initial | 2026-10-19 | Documented the reported development concept and evidence gaps to provide a field-level portfolio reference. |
| 1 | 2026-10-20 | Formatted whole-number inputs without decimal padding for readability. |
Engineering rationale
The reported arrangement combines drilling, workover and production on an extended tension-leg platform. Dry trees and top-tensioned risers provide direct well access from the facility. This is a description of the reported selection, not a fresh comparison of host concepts.
Field parameters
| Input | Value | Source and scope |
|---|---|---|
| Operator at source date | Chevron | S1: Operator identified in the project overview. |
| Reported development concept | tlp | S1: Floating, drilling and production facility section identifies the extended tension-leg platform and dry trees. |
| Host | Extended tension-leg drilling and production platform | S1: Floating, drilling and production facility section; no vessel identity is needed. |
| Water depth (m) | Unknown | Required input; not established by the cited evidence. |
| Wells (scope stated below) | Unknown | Required input; not established by the cited evidence. |
| Designed peak capacity (boe/d) | Unknown | Required input; not established by the cited evidence. |
| Reported oil capacity (bbl/d; not a boe/d plateau) | 75000 | S1: Facility section reports 75,000 barrels of oil per day; gas capacity is separate. This is facility capacity, not a boe/d production plateau. |
| Recoverable resources (MMboe) | Unknown | Required input; not established by the cited evidence. |
| Actual first-oil year | 2018 | S1: Overview reports the field came on stream in November 2018. |
Architecture
Dry-tree wellheads on the platform connect through top-tensioned risers; processed fluids leave through export infrastructure. No subsea wet-tree layout is implied.
Well coordinates, manifold counts and interconnection lengths are required inputs for a detailed layout. Layout: NOT_EVALUATED; no assumed geometry is drawn.
Recommended concept shortlist
NOT_EVALUATED. The reported concept is documented above; a comparative ranking requires sourced screening limits and criteria weights.
Economics and execution
NOT_EVALUATED. No cost or investment return is inferred from facility capacity. Required inputs include scope-matched capital cost, operating cost, production profile, prices, discount rate and schedule. Equipment qualification and installation feasibility also require project-specific design evidence.
Known limits and way forward
The source gives inconsistent water-depth figures, so metric water depth is unknown here. Initial producer and injector plans are not an installed-well inventory; well count remains null. Obtain a dated well inventory and facility design basis before drawing a detailed layout or evaluating costs.
Sources
Input citations refer to the source dates below. Capacity, planned well count and forecast startup are not measured production.
- Big Foot Oil Field, Gulf of Mexico (2018-12-10; secondary publisher report). Retrieved 2026-10-20T06:51:51.539338+00:00; HTTP 200; SHA-256: 12736919cc83bf08a005adba71dc29331fedb810087832a2e905192952803bf7.