Tanzania’s upstream oil and gas landscape is shifting toward onshore natural gas, while offshore value remains anchored in LNG.
The clearest near-term exploration signal is the Mnazi Bay area’s Kasa-1X discovery, estimated at 223 billion cubic feet, whereas the offshore LNG resource base tied to Equinor and Shell’s $42 billion project is much larger at 47.13 trillion cubic feet.
That split matters because it points to different commercial timelines: onshore gas is the current momentum story, while offshore remains a long-duration LNG monetization play.
Official messaging has also emphasized accelerating exploration, which reinforces the view that Mnazi Bay and the south basin are the immediate focus.
Market access remains highly state-mediated. PURA regulates upstream licensing, while TPDC sits at the center of acreage access and commercialization pathways.
The practical result is that most attractive assets are either TPDC-linked or tied to incumbent operators, making partnership routes more realistic than waiting for broad new acreage liberalization.
Offshore Block 1&4, operated by Shell, is still waiting on Host Government Agreement completion before pre-development can advance, while Block 2 remains Equinor-operated. Onshore, Mnazi Bay, Songo Songo, Kiliwani North and Ntorya are the main domestic gas entry points.
The near-term pipeline is led by Ntorya and Mnazi Bay rather than new offshore developments.
Ntorya’s 2026–2027 gross work programme is budgeted at up to $75 million, with NT-2 testing scheduled for November 2026 and production into Ntorya–Madimba targeted for December 2026.
TPDC said roughly 95% of pipelaying and infilling was complete by late September 2026, leaving tie-in and testing as the main execution gates. Mnazi Bay is already producing, with Maurel & Prom reporting 58.7 mmcfd for H1 2025 on its working-interest basis. Reuters also reported the 223 bcf Kasa discovery in the Mnazi Bay area, with first gas potentially starting as early as the following month.
Tanzania LNG remains pre-FID as of October 2026. Despite the project’s scale and sponsor strength, including Equinor, Shell, ExxonMobil, Pavilion, Medco and TPDC, the project has not yet reached final investment decision. Reuters still describes it as a $42 billion development, with first production only expected roughly eight years after agreement signing.
That keeps the flagship LNG project outside the near-term investment window. The nearer monetization route is mini-LNG, helped by Tanzania’s 2026 regulatory rules that create a legal path for smaller-scale domestic and cross-border gas commercialization ahead of the main LNG train.
The regulatory framework is stable enough to support entry, with the Petroleum Act 2015 still the core statute, local content requirements in force, and 2026 upstream dispute-settlement regulations published. But execution risk remains the main issue. LNG is still awaiting FID, Ntorya required a revised implementation plan, and offshore progress still depends on government agreement completion.
Regional competition, especially from Mozambique, also raises the cost of delay.
The investment case works if domestic gas demand continues to absorb new southern supply and if HGA-to-FID conversion finally happens. It weakens if Ntorya slips again, mini-LNG opportunities do not materialize, or LNG negotiations continue into the 2030s
