Executive Summary
Tanzania FYDP IV Energy Sector — Strategic Overview
The Energy Sector is one of the most strategically critical pillars of Tanzania's Fourth Five-Year Development Plan (FYDP IV) covering 2026/27 to 2030/31 — the inaugural milestone of the Dira ya Maendeleo 2050 long-term transformation agenda. The Plan envisions transforming Tanzania from a nation with significant energy deficits into a regional power hub with 15,000 MW of installed capacity by 2031, universal household connectivity by 2050, and a green-industrial revolution underpinned by hydro, solar, wind, geothermal, and gas resources.
This analysis — produced by TICGL — extracts and synthesises all energy-related content from FYDP IV, including the main sector chapter, Annex I (detailed interventions), Annex II (KPI framework), Oil & Gas sector, and Flagship Programme references, into a single data-rich reference with full statistical tables, investment targets, and structured intervention roadmaps.
The Core Challenge: Quadrupling Tanzania's Entire Electricity System in Five Years
Tanzania must increase installed electricity capacity from 4,032 MW to 15,000 MW — a 272% expansion — between 2025 and 2031. The country's entire generation infrastructure took several decades to reach 4,000 MW. This is the defining infrastructure challenge of FYDP IV.
Installed Capacity Target
From baseline to 2031 target
4,032 → 15,000 MWHousehold Connectivity
National rate by 2031
49% → 55.2%Clean Cooking Access
Share of households using clean energy
30% → 66%System Loss Reduction
Technical & commercial losses
14.2% → 12.4%Rural Electrification
Rural household rate target
36% → 42.8%Per Capita Consumption
kWh per person per year
170 → 600 kWhSector Snapshot: Key Performance Indicators
FYDP IV Outcome-Level KPIs — Annex II, Section 3.6.1
Installed Electricity Capacity — Baseline vs Target
MW comparison: 2025 baseline against 2030/31 FYDP IV target (log-scaled bar)
Household Electrification Progress Targets
National & rural connectivity rates: baseline vs 2031 target
Table 1.1 — Outcome-Level Key Performance Indicators: Energy Sector (Annex II, Section 3.6.1)
| # | Indicator | Baseline (2025) | Target (2030/31) | Change | Data Source |
|---|---|---|---|---|---|
| i | Installed Electricity Capacity | 4,032 MW | 15,000 MW | +272% | CCM Election Manifesto; EWURA 2024/25 |
| ii | Per Capita Electricity Consumption | 170 kWh | 600 kWh | +253% | Ministry of Energy (MoE) |
| iii | Electricity System Losses (Technical & Commercial) | 14.2% | 12.4% | −1.8 pp | TANESCO Annual Reports; EWURA; MoE |
| iv | National Household Connectivity Rate | 49% | 55.2% | +6.2 pp | Ministry of Energy (MoE) |
| v | Rural Household Electrification Rate | 36% | 42.8% | +6.8 pp | Ministry of Energy (MoE) |
| vi | Household Electricity Reliability | <50–60% (rural) | ≥80% | +20–30 pp | TANESCO SCADA; MoE; REA |
| vii | Households Using Clean Cooking Energy | 30% (2022) | 66% | +36 pp | Ministry of Energy (MoE) |
Table 1.2 — Oil & Gas Sector KPIs: Strategic Energy Supply Inputs (Section 3.3.5)
| # | Indicator | Baseline | Target (2030/31) | Source |
|---|---|---|---|---|
| i | Natural Gas Production | 69,538.30 MMSCF/year (2024) | 90,000 MMSCF/year | MoE / TPDC |
| ii | Coverage of Natural Gas Distribution Network | 177.82 km (2024) | 267.00 km | TPDC / MoE |
| iii | Share of Natural Gas in Total Electricity Supply Mix | 63% (2024) | 45% | MoE / TANESCO |
| iv | Natural Gas Pipeline Capacity (Domestic Utilisation) | 400 MMSCFD | 800 MMSCFD | TPDC |
Current Status & FYDP III Achievements
Tanzania's energy sector position at the start of FYDP IV (2026)
Tanzania Electricity Generation Mix — 2024/25 Baseline
Share of electricity generation by source at FYDP IV entry point
Key Energy Metrics — Trend to 2031
Indexed performance trajectory across major KPIs (Base = 2025)
Table 2.1 — FYDP III Energy Sector Achievements & Status at FYDP IV Entry
| Area | Category | Status / Detail | Assessment |
|---|---|---|---|
| Generation Capacity (Installed) | FYDP III Achievement | 4,215 MW reached by 2024 under FYDP III; 4,032 MW installed capacity entering FYDP IV (2025) | Positive |
| Household Access Rate | FYDP III Achievement | National household connectivity reached 54%; nearly 90% of villages connected to the national grid | Positive |
| Rural Electrification | Current Gap | Rural household electrification remains below 36% — significantly lagging urban connectivity | Challenge |
| Energy Generation Mix | Current Status | Dominated by natural gas (63%) and hydro. Renewables (solar, wind, geothermal) contribute less than 2% of total electricity generation | Challenge |
| Supply Reliability | Current Challenge | Reliability below 50–60% in rural areas; frequent outages limiting industrial productivity | Critical |
| Transmission & Distribution Losses | Current Challenge | Total system losses at 14.2%, above the acceptable benchmark; commercial losses compounding technical losses | Challenge |
| Natural Gas Sector | FYDP III Achievement | 57 trillion cubic feet proven reserves; Mnazi Bay, Songo Songo, and Kiliwani fields operational; gas powering ~63% of electricity generation | Positive |
| LNG Export Project (Lindi) | In Progress | Final Investment Decision (FID) at advanced stage as of 2025; Lindi LNG terminal development ongoing | In Progress |
| TANESCO Institutional Structure | Structural Challenge | Vertically integrated structure with generation, transmission, and distribution under one entity; significant financial constraints and outdated systems | Critical |
| Clean Cooking Energy Access | Current Gap | Only 30% of households using clean cooking energy (2022 baseline); significant health and environmental impact | Challenge |
| Demand Projection to 2050 | Long-Term Requirement | Electricity demand projected to exceed 70,000 MW by 2050 as Tanzania targets upper-middle-income status | Planning Target |
Table 2.2 — Tanzania's Current Electricity Generation Mix (2024/25 Baseline)
| Source | Share | Key Assets / Locations | Stage | FYDP IV Direction |
|---|---|---|---|---|
| Natural Gas | ~63% | Dominant source; Mnazi Bay, Songo Songo, Kiliwani fields | Mature | Targeting reduction to ~45% by 2030/31 |
| Hydro (Large) | ~30–33% | JNHPP (Julius Nyerere), Kidatu, Mtera, Ruhuji (planned), Rumakali (planned) | Major expansion planned | Ruhuji + Rumakali commissioning by 2031 |
| Coal | <5% | Kiwira coal; limited utilisation | Expansion planned | 1,000 MW clean coal target by 2031 |
| Renewables (Solar, Wind, Geothermal) | <2% | Small-scale; significant untapped potential | Early-stage scale-up | 1,700 MW geothermal; 500 MW wind; 715 MW solar targeted |
| Imports (Regional Grid) | Minimal | Limited cross-border electricity exchange via SAPP/EAPP | Interconnector gaps | 400kV regional interconnectors planned by 2031 |
Structural Challenges in Tanzania's Energy Sector
FYDP IV Section 3.6.1 — Identified Barriers to Development
FYDP IV explicitly identifies ten structural, financial, and institutional challenges constraining the energy sector. These challenges form the basis for the strategic objective and intervention framework under FYDP IV. The table and cards below categorise each challenge by priority and impact domain.
1. Rural Energy Access Gap HIGH
Rural electrification below 36%; supply reliability under 50–60% in rural zones; insufficient off-grid solutions for dispersed communities.
2. Renewable Energy Underdevelopment HIGH
Renewables at <2% of generation mix despite vast hydro, solar, wind, geothermal, and uranium resources across Tanzania.
3. TANESCO Structural Constraints CRITICAL
Vertically integrated structure hinders efficiency; outdated systems; weak financial position; limited private participation in generation or distribution.
4. Transmission & Distribution Losses HIGH
System losses at 14.2%; aging transformers, urban feeders, and grid infrastructure driving persistent technical and commercial losses.
5. Private Investment Barriers HIGH
Limited private investment due to lack of competitive market structure; absence of Independent System & Market Operator (ISMO).
6. Skills Shortage MEDIUM
Insufficient energy professionals; limited digital grid management capacity; skills gap in clean energy technologies and advanced grid operations.
7. Climate Vulnerability MEDIUM
Climate-related impacts on hydro generation; hydropower dependent on rainfall variability; long-term resilience of the generation mix at risk.
8. Regional Interconnection Gaps MEDIUM
Insufficient 400kV interconnectors with Kenya, Uganda, Zambia; non-aligned grid codes with SAPP/EAPP standards.
9. Regulatory Modernisation Lag MEDIUM
EWURA regulatory environment requires modernisation; tariff regime not fully cost-reflective; weak project preparation frameworks.
10. Clean Cooking Energy Access HIGH
70% of households still dependent on biomass/traditional fuels; significant health, deforestation, and carbon emission implications nationwide.
Table 3.1 — Structural Challenges Summary (FYDP IV Section 3.6.1)
| # | Challenge | Category | Priority |
|---|---|---|---|
| 1 | Rural Energy Access Gap | Institutional / Geographic | High |
| 2 | Renewable Energy Underdevelopment | Technology / Investment | High |
| 3 | TANESCO Structural Constraints | Institutional / Financial | Critical |
| 4 | Transmission & Distribution Losses | Infrastructure / Technical | High |
| 5 | Private Investment Barriers | Regulatory / Financial | High |
| 6 | Skills Shortage | Human Capital | Medium |
| 7 | Climate Vulnerability | Environmental | Medium |
| 8 | Regional Interconnection Gaps | Infrastructure / Cross-Border | Medium |
| 9 | Regulatory Modernisation Lag | Regulatory | Medium |
| 10 | Clean Cooking Energy Access | Social / Environmental | High |
Strategic Objectives & Intervention Framework
FYDP IV Annex I, Section 3.6.1 — 8 Objectives, 2026/27–2030/31
FYDP IV Annex I defines 8 strategic objectives for the energy sector, each with specific milestone targets and detailed interventions sequenced over the five-year plan period. The objectives span governance, institutional reform, infrastructure resilience, generation expansion, renewable integration, grid modernisation, universal access, and energy security.
Objective 1: Modern Energy Sector Governance & Skilled Workforce
Tanzania's energy sector is governed by modern, transparent and efficient institutions, supported by a skilled workforce ensuring reliable service delivery, innovation and long-term sustainability.
Table 4.1a — Quantified Targets: Objective 1
| Ref | Target Statement | Deadline |
|---|---|---|
| T1.1 | At least 10,000 energy professionals certified nationally | June 2031 |
| T1.2 | Transparent, efficient and accountable governance framework in place | June 2031 |
Table 4.1b — Key Interventions: Objective 1
| Ref | Intervention | Milestone |
|---|---|---|
| I1.1 | Develop and operationalise the National Energy Skills Development Programme (NESDP) | June 2027 |
| I1.2 | Design and implement accreditation framework for energy professionals | June 2029 |
| I1.3 | Develop and implement transparent Energy Sector Governance Code and Anti-Corruption Framework | June 2031 |
| I1.4 | Implement energy sector digital information management system (EDIMS) for planning, monitoring, and reporting | June 2031 |
Objective 2: Full Corporatisation & Unbundling of TANESCO
TANESCO fully corporatised and unbundled into autonomous State-Owned Enterprises for Generation (G), Transmission (T), and Distribution (D), with an Independent System and Market Operator (ISMO) established by 2031.
Table 4.2b — Key Interventions: Objective 2 (TANESCO Reform)
| Ref | Intervention | Milestone |
|---|---|---|
| I2.1 | Implement comprehensive institutional and financial restructuring through independent audit, restructuring roadmap, and regulatory alignment | June 2031 |
| I2.2 | Institute separation of accounts and management structures for Generation, Transmission, and Distribution | June 2031 |
| I2.3 | Enact enabling legislation to liberalise the sector; corporatise autonomous SOEs for G, T, D | June 2031 |
| I2.4 | Implement cost-reflective, transparent tariff regime to reduce subsidies and attract private investment | June 2031 |
| I2.5 | Introduce performance-based regulation and management contracts to improve efficiency and reduce losses | June 2031 |
| I2.6 | Develop regulatory, governance and operational framework for ISMO in collaboration with EWURA; fully operationalise | By 2028; June 2031 |
| I2.7 | Designate and capacitate EWURA to develop and oversee the National Energy Master Plan | By 2027 |
Objective 3: Resilient, Investment-Ready Energy Infrastructure & Green Finance
Tanzania has resilient, integrated and investment-ready energy infrastructure ensuring reliable domestic supply, facilitating cross-border electricity exchange, and financed through sustainable public-private and green capital partnerships.
Table 4.3a — Quantified Targets: Objective 3
| Ref | Target Statement | Deadline |
|---|---|---|
| T3.1 | At least one regional 400kV cross-border interconnector (Tanzania–Zambia, Uganda, Kenya) constructed | June 2031 |
| T3.2 | National transmission backbone upgraded to 400kV standards across priority corridors | June 2031 |
| T3.3 | SCADA systems and smart grid technologies deployed to at least 90% of all regional control centres | June 2031 |
| T3.4 | At least USD 7 billion in green and concessional finance mobilised for clean energy generation, transmission and access initiatives | June 2031 |
| T3.5 | Grid codes and protocols aligned with SAPP and EAPP standards by at least 70% | June 2031 |
Objective 4: Expand Installed Capacity to 15,000 MW (Path to 70,000 MW by 2050)
Per Capita Energy Consumption — Progress to Target
kWh per person: baseline 2025 through 2031 target trajectory
Renewable Energy Expansion by Source — 2031 Targets (MW)
Planned installed capacity additions by renewable technology type
Table 4.4b — Key Interventions: Objective 4 (Capacity Expansion)
| Ref | Intervention | Milestone |
|---|---|---|
| I4.1 | Fast-track large-scale clean energy generation (hydro, solar, wind, geothermal, gas, nuclear) | By 2029 |
| I4.2 | Develop integrated generation expansion master plan | June 2031 |
| I4.3 | Commission major hydro projects (Ruhuji and Rumakali), solar, wind and geothermal plants in phases | June 2031 |
| I4.4 | Develop and operationalise a 1,000 MW nuclear pilot plant | June 2031 |
| I4.5 | Implement incentive schemes and competitive auctions for Independent Power Producers (IPPs) | June 2031 |
| I4.6 | Subsidise household connections and off-grid technologies | June 2031 |
Objective 5: Increase Renewable Energy Share to at Least 50% of the Generation Mix
Table 4.5a — Quantified Targets: Objective 5 (Renewable Energy)
| Ref | Target Statement | Deadline |
|---|---|---|
| T5.1 | 1,700 MW geothermal, 500 MW wind, and 715 MW solar generated | June 2031 |
| T5.2 | 40% of national electricity generation sourced from renewables | June 2031 |
| T5.3 | National grid upgraded to integrate 80% of intermittent RE capacity | June 2031 |
| T5.4 | 300 MW of community mini-grids deployed | June 2031 |
Table 4.5b — Key Interventions: Objective 5 (Renewable Energy)
| Ref | Intervention | Milestone |
|---|---|---|
| I5.1 | Review and harmonise RE regulatory frameworks | June 2027 |
| I5.2 | Accelerate RE licensing and environmental approval procedures; set clear timelines and enhance institutional coordination | June 2031 |
| I5.3 | Establish a One-Stop Centre for RE approvals | June 2031 |
| I5.4 | Modernise grid infrastructure (SCADA/EMS, FACTS, battery storage, interconnections) to support 80% RE integration | June 2031 |
| I5.5 | Establish renewable energy manufacturing zones and innovation centres | June 2031 |
| I5.6 | Establish competitive RE auctions and green financing mechanisms | June 2031 |
| I5.7 | Facilitate deployment of 300 MW community mini-grids | June 2031 |
| I5.8 | Institutionalise climate-resilient planning and deploy disaster-ready solar storage systems | June 2031 |
Objective 6: Modernise Transmission & Distribution — Reduce Losses to Below 5%
Loss Reduction Progress Indicators
Objective 7: Universal Household Electricity Access
Table 4.7a — Quantified Targets: Objective 7 (Access)
| Ref | Target Statement | Deadline |
|---|---|---|
| T7.1 | National household electricity connectivity increased from 49% to 55.2% | June 2031 |
| T7.2 | Rural connectivity increased from 36% to 42.8% | June 2031 |
| T7.3 | Connect at least 4 million new households | June 2031 |
| T7.4 | Household-level electricity reliability improved to at least 80% | June 2031 |
Objective 8: Energy Security via Diversified & Environmentally Compliant Generation Mix
Table 4.8a — Quantified Targets: Objective 8 (Energy Security)
| Ref | Target Statement | Deadline |
|---|---|---|
| T8.1 | At least 1,000 MW of environmentally compliant coal-fired capacity installed | June 2031 |
| T8.2 | Maintain a 20% grid reserve margin | June 2031 |
| T8.3 | Grid-connected generation capacity expanded by additional 1,500 MW through gas, hydro, and flexible renewable systems | June 2031 |
All 8 Strategic Objectives — Summary Overview
| Obj. | Title | Key Targets | Lead Entities |
|---|---|---|---|
| 1 | Modern Governance & Skilled Workforce | 10,000 certified professionals by 2031 | MoE; NESDP |
| 2 | TANESCO Corporatisation & Unbundling | 3 independent SOEs (G, T, D) + ISMO operational | MoE; EWURA; TANESCO |
| 3 | Resilient Infrastructure & Green Finance | USD 7bn mobilised; 400kV interconnectors; 90% SCADA coverage | GoT; MDBs; Climate Funds |
| 4 | Expand Capacity to 15,000 MW | 15,000 MW installed; 600 kWh per capita; nuclear pilot | MoE; IPPs; TANESCO |
| 5 | Increase Renewables to ≥50% | 1,700 MW geothermal; 715 MW solar; 500 MW wind; 300 MW mini-grids | MoE; REA; Private Sector |
| 6 | Modernise T&D — Losses Below 5% | Losses to 12.4%; 100 rural substations; 1,000 km feeder upgrades | TANESCO; EWURA |
| 7 | Universal Household Access | 4 million new connections; 55.2% national; 42.8% rural; ≥80% reliability | TANESCO; REA; MoE |
| 8 | Energy Security & Diversified Mix | 1,000 MW clean coal; 20% reserve margin; 1,500 MW additional capacity | MoE; PPPC; Private Investors |
Full Report Navigation
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Tanzania FYDP IV Energy Sector — All Sections
Renewable Energy Targets by Source (2026/27–2030/31)
FYDP IV Objective 5 — Section 3.6.1 & Annex I 3.6.1
FYDP IV specifies disaggregated renewable energy generation targets by source for the plan period. These targets are drawn from Objective 5 of the Energy Chapter and are to be read alongside the broader generation capacity expansion target of 15,000 MW. Tanzania is making a historic leap: from less than 2% renewables in the generation mix to at least 40% by 2030/31, anchored primarily by a 1,700 MW geothermal programme exploiting the East African Rift System.
Renewable Capacity Targets by Technology — 2031 (MW)
Horizontal bar showing the scale of each RE source's 2031 installed capacity target
Generation Mix Transformation — 2025 vs 2031
How the electricity mix shifts from gas-dominated to diversified & renewable-led
Table 5.1 — Renewable Energy Generation Targets by Source: FYDP IV (2030/31)
| RE Source | Current Status (2025) | FYDP IV Target (2030/31) | Scale of Addition | Notes & Strategy |
|---|---|---|---|---|
| Geothermal | 0 MW (operational) | 1,700 MW | +1,700 MW | Primary new RE source; Tanzania sits on the East African Rift System with substantial untapped resources estimated at 5,000+ MW exploitable potential |
| Solar PV (Grid-Connected) | ~50–100 MW (estimated) | 715 MW | +615–665 MW | Competitive auctions; RE manufacturing zones; mini-grid expansion; falling technology costs support scale-up feasibility |
| Wind | ~0–50 MW (estimated) | 500 MW | +450–500 MW | Grid-connected utility-scale wind; supported by green financing mechanisms; sites in high-wind corridors to be developed |
| Community Mini-Grids (all RE types) | ~30–50 MW (estimated) | 300 MW | +250–270 MW | Off-grid and weak-grid areas; private developers under performance-based incentives; critical for rural last-mile access |
| Large Hydro (new additions) | Ruhuji & Rumakali under construction | Major MW additions (TBC in Generation Master Plan) | Substantial + | Ruhuji and Rumakali hydropower plants to be commissioned in phases by June 2031; exact MW confirmed in National Generation Expansion Plan |
| Nuclear (Pilot) | 0 MW | 1,000 MW (pilot) | +1,000 MW | 1,000 MW nuclear pilot plant to be developed and operationalised by June 2031; financing through GoT, strategic partners, and technology providers; IAEA collaboration expected |
| Total RE Share of Mix | <2% of generation (2025) | ≥40% of national electricity generation by 2030/31 | +38 pp | National grid to be upgraded to integrate 80% of intermittent RE capacity; SCADA/EMS and battery storage systems required |
Renewable Energy Achievement Progress Tracker (2031 Targets)
*Progress bars show 2025 starting position against 2031 targets. Bars animate toward full completion to visualise the required scale of delivery.
Energy Sector Institutional Reform Roadmap
TANESCO Corporatisation & Full Unbundling — 5 Phases to 2031
One of the most consequential and structurally complex components of FYDP IV's energy programme is the full corporatisation and unbundling of TANESCO — Tanzania's national electricity utility. This reform is central to unlocking private investment, improving operational efficiency, and establishing a competitive electricity market. The plan calls for TANESCO to be fully unbundled into three separate, autonomous State-Owned Enterprises (Generation, Transmission, and Distribution) by June 2031, with an Independent System and Market Operator (ISMO) functioning as a neutral dispatch authority.
TANESCO Unbundling — Reform Phase Timeline
Five-phase structural transformation from integrated utility to competitive market (2026–2031)
TANESCO Post-Unbundling Structure
Target market architecture: three autonomous SOEs plus ISMO dispatch authority
Table 6.1 — TANESCO Corporatisation & Energy Sector Unbundling: Reform Milestones
Institutional Audit & Framework Development
Independent financial and operational audit of TANESCO; development of the restructuring roadmap; regulatory alignment with EWURA; Code of Corporate Governance drafted.
Governance Reforms & Legal Framework
Enact enabling legislation for sector liberalisation; separate accounts and management structures for Generation (G), Transmission (T), and Distribution (D); ISMO governance framework developed; EWURA capacity-built for National Energy Master Plan oversight.
Structural Separation & Market Development
Formal separation of TANESCO into autonomous SOEs for Generation, Transmission, and Distribution; ISMO operationalisation begins; cost-reflective tariff regime introduced; first IPP competitive auction conducted.
Private Sector Market Entry
Private sector entry into generation and distribution entities; performance-based management contracts implemented; ISMO assumes full dispatch authority; open access rules operationalised.
Full Market Operationalisation
TANESCO fully unbundled — three independent SOEs (Generation, Transmission, Distribution) operational; ISMO fully operational with competitive power market coordination; USD 7 billion green finance target achieved.
| Phase | Year | Stage | Key Actions | Lead Institutions |
|---|---|---|---|---|
| Phase 1 | 2026/27 | Institutional Audit & Framework Development | Independent audit; restructuring roadmap; regulatory alignment; Corporate Governance Code drafted | MoE; EWURA; TANESCO |
| Phase 2 | 2027/28 | Governance Reforms & Legal Framework | Enabling legislation enacted; G/T/D account separation; ISMO governance framework; EWURA capacitated for Energy Master Plan | MoE; Ministry of Justice; EWURA; Parliament |
| Phase 3 | 2028/29 | Structural Separation & Market Development | Formal G/T/D separation into autonomous SOEs; ISMO operationalisation begins; cost-reflective tariff introduced; first IPP auction | MoE; EWURA; ISMO; TANESCO |
| Phase 4 | 2029/30 | Private Sector Market Entry | Private sector enters generation & distribution; performance-based contracts; ISMO full dispatch authority; open access rules | ISMO; EWURA; Private Investors |
| Phase 5 | 2030/31 | Full Market Operationalisation | TANESCO fully unbundled into 3 SOEs; ISMO coordinates competitive power market; USD 7bn green finance achieved | All MDA stakeholders |
Energy Investment & Financing Framework
FYDP IV Multi-Source Capital Architecture — USD 7bn+ Target
FYDP IV envisions a multi-source financing architecture combining public investment, private capital (including IPPs), blended finance facilities, Multilateral Development Bank (MDB) concessional funding, and climate/green finance. The headline target is mobilising at least USD 7 billion in green and concessional finance by June 2031. International benchmarks suggest average energy project costs of USD 1–2 million per MW — implying a total capital requirement of USD 11–22 billion for generation alone, making the private sector imperative.
Energy Investment Requirement Estimate vs Target Finance
USD billions: green finance target vs estimated total capital need for 11,000 MW addition
Estimated Financing Source Composition
Projected share of the total energy capital requirement by funding stream type
Green & Concessional Finance
USD 7 billionTotal mobilisation target for clean energy generation, transmission and access initiatives. Administered through the Clean Energy Blended Finance Facility.
Clean Energy Blended Finance Facility
Framework TBDDedicated facility to be operationalised by June 2031; framework developed by June 2028. Combines concessional public finance with private capital to de-risk renewable energy investments.
Private Sector / IPP Investment
Via Competitive AuctionsCompetitive auctions for Independent Power Producers (IPPs) introduced by 2031. Open market entry for generation and distribution entities under the post-unbundling TANESCO structure.
PPP Structures
Multiple ProjectsPPP instruments for coal generation (clean technology), mini-grids, rural electrification, and distribution network operators. Coordinated by the Public-Private Partnership Centre (PPPC).
MDB Partnerships
TBD Per ProjectWorld Bank, African Development Bank, EIB, and AIIB partnerships for transmission infrastructure, renewable generation, and access programmes. Concessional loan terms targeted.
National Green Taxonomy
FrameworkDeveloped alongside the Green Finance Facility by 2031 to classify qualifying clean energy investments and unlock international ESG capital flows into Tanzania's energy sector.
Table 7.1 — Energy Sector Financing Targets & Instruments (FYDP IV)
| Financing Instrument | Target Amount | Description & Timeline | Key Parties |
|---|---|---|---|
| Green & Concessional Finance | USD 7 billion | Total mobilisation target for clean energy generation, transmission and access initiatives by June 2031 | Clean Energy Blended Finance Facility; MDBs; Climate Funds |
| Clean Energy Blended Finance Facility | Framework TBD | Dedicated facility operationalised by June 2031; framework developed by June 2028 | GoT; Multilateral Development Banks; Climate Funds (GCF, AF, etc.) |
| Private Sector / IPP Investment | Determined via auctions | Competitive auctions for IPPs introduced by 2031; open market entry for Generation and Distribution entities | Independent Power Producers; Private Equity; Infrastructure Funds |
| PPP Structures | Multiple projects | PPP instruments for coal, generation, mini-grids, rural electrification; projects in generation, distribution, mini-grids | PPPC; MoE; Private Investors; DFIs |
| National Green Taxonomy | Framework | Developed alongside Green Finance Facility by 2031 to classify qualifying clean energy investments | GoT; MoE; Ministry of Finance |
| MDB Partnerships | TBD per project | World Bank, AfDB, EIB, AIIB partnerships for transmission infrastructure, renewable generation, and access programmes | GoT; MoE; MDBs; Climate Finance Institutions |
| LNG Project (FDI / FID) | Multi-billion USD | Final Investment Decision at advanced stage (2025); transformational FDI for LNG export terminal and associated industrial cluster | TPDC; International Oil Companies; GoT |
| Nuclear Plant (Pilot) | USD estimate TBD | 1,000 MW nuclear pilot plant financing to be mobilised through government, strategic partners, and technology providers | GoT; IAEA; Strategic Partners |
Oil & Gas: Strategic Role in Tanzania's Energy Sector
FYDP IV Section 3.3.5 — From Domestic Supplier to Regional Energy Hub & Global LNG Exporter
The Oil and Gas sector under FYDP IV is treated as a critical enabler of energy security, industrialisation, and fiscal resilience. With approximately 57 trillion cubic feet of proven natural gas reserves — among the largest in Sub-Saharan Africa — Tanzania has the foundation to transition from a domestic power supplier to a regional energy hub and global LNG exporter. The concurrent domestic gas strategy ensures LNG export does not come at the cost of domestic industrialisation, with pipeline capacity targeted to double from 400 to 800 MMSCFD by 2031.
Natural Gas Production — Baseline vs 2031 Target
MMSCF per year: 2024 baseline against 2030/31 FYDP IV target (+29%)
Gas Share in Electricity Mix — Planned Reduction
Strategic diversification: gas share declines as renewables scale up (2024–2031)
Natural Gas Production & Distribution
LNG Export — Lindi Terminal Project
Domestic Gas Utilisation Strategy
Table 8.1 — Oil & Gas Sector: Strategic Targets & Interventions (FYDP IV Section 3.3.5)
| Strategic Area | Baseline | Target (2030/31) | Key Interventions |
|---|---|---|---|
| Natural Gas Production | 69,538 MMSCF/year (2024) | 90,000 MMSCF/year | Onshore gas field expansion; Mnazi Bay, Songo Songo, Kiliwani development; upstream field optimisation |
| Gas Distribution Network | 177.82 km (2024) | 267.00 km | Expand distribution network; connect major industrial clusters to pipeline supply; CNG development |
| Natural Gas Share in Electricity Mix | 63% (2024) | 45% (2030/31) | Diversification of generation mix; increase renewables; reduce over-dependence on single fuel source |
| Domestic Gas Utilisation Capacity | ~400 MMSCFD | ~800 MMSCFD | Foster in-country natural gas utilisation; convert major industrial clusters to natural gas by 2028 |
| LNG Export Terminal (Lindi LNG) | FID at final stage (2025) | LNG capacity operational; FID achieved | Stable regulatory and fiscal framework; LNG processing plant establishment; coastal industrial cluster development |
| Proven Natural Gas Reserves | ~57 Trillion Cubic Feet | Maintained / expanded via new exploration | Gas reserve protection; downstream monetisation strategy; petrochemicals and fertiliser value chain development |
| TPDC Institutional Capacity | Current operational status | World-class NOC operations | Transform TPDC into world-class national oil corporation; Centre of Excellence for skills development |
| Regional Gas Trade Hub | Limited cross-border trade | Premier EAC/SADC gas trading hub | Cross-border infrastructure; harmonised regional trade policies; gas pipeline interconnectors |
Enabling Areas & Cross-Cutting Monitoring Indicators
FYDP IV Annex II, Section 3.6.1 — Conditions for Achieving Energy KPIs
FYDP IV Annex II identifies five key enabling areas — cross-cutting domains whose performance will determine whether the outcome-level energy KPIs are achieved. Each enabling area is paired with an indicative enabling indicator for ongoing monitoring throughout the plan period. These represent the systemic preconditions that must be in place for sector interventions to translate into measurable outcomes.
Table 9.1 — Indicative Enabling Areas & Monitoring Indicators: Energy Sector (Annex II, Section 3.6.1)
| # | Enabling Area | Indicative Enabling Indicator | Why It Matters |
|---|---|---|---|
| vii | Renewable Energy; Finance; Power Sector Reform | Percentage of total energy investment allocated to renewable energy (public and private combined) | Measures whether capital flows are actually being redirected toward the clean energy transition — a critical proxy for reform implementation |
| viii | Power Generation & Distribution; Infrastructure; Private Sector Engagement | Number of energy-related PPP projects initiated or operational (generation, distribution, mini-grids) | Tracks the pace of private sector entry into the energy market — essential for mobilising the investment required to reach 15,000 MW |
| ix | Governance & Regulation; Policy Environment | Number of fully implemented national policies or strategies supporting clean energy transition | Monitors the regulatory enabling environment; policy gaps are a primary cause of investment delays in Tanzania's energy sector |
| x | Technology; Innovation; Efficiency | Public and private R&D expenditure on clean energy technologies as % of national energy budget | Indicates whether Tanzania is building long-term domestic technology capacity or remaining dependent on imported solutions |
| xi | Access; Rural Electrification; Social Inclusion | Proportion of energy access projects targeting underserved areas (% of total projects) | Ensures that investment and project activity reaches the most disadvantaged communities — tracking equity in the energy transition |
Enabling Area Weight & Interconnection
Relative importance of each enabling domain to FYDP IV energy outcome achievement
Cross-Cutting Enablers — FYDP IV Energy KPI Dependencies
Share of energy sector KPIs dependent on each enabling area being in place
FYDP IV Energy Sector Master Scorecard
All Quantified Targets — Baseline, 2031 Target & Required Change
The following master scorecard consolidates all quantified energy sector targets under FYDP IV into a single reference view. It presents baseline values, end-of-plan targets, the magnitude of change required, and the responsible monitoring entity. This is the primary accountability framework for Tanzania's energy sector transformation between 2026 and 2031.
FYDP IV Energy Sector — Full Target Dashboard (Baseline vs 2031)
Complete side-by-side comparison of all quantified energy targets: current baseline against 2030/31 end-of-plan values
Table 10.1 — FYDP IV Energy Sector Master Scorecard: All Quantified Targets
| Target Area | Baseline | 2030/31 Target | Change Required | Source / Monitor |
|---|---|---|---|---|
| Installed Electricity Capacity | 4,032 MW | 15,000 MW | +10,968 MW (+272%) | EWURA / MoE |
| Per Capita Electricity Consumption | 170 kWh | 600 kWh | +430 kWh (+253%) | MoE |
| Electricity System Losses | 14.2% | 12.4% | −1.8 pp | TANESCO / EWURA |
| National Household Connectivity | 49% | 55.2% | +6.2 pp | MoE / REA |
| Rural Electrification Rate | 36% | 42.8% | +6.8 pp | MoE / REA |
| Household Electricity Reliability | <50–60% | ≥80% | +20–30 pp | TANESCO / MoE |
| Clean Cooking Energy Access | 30% (2022) | 66% | +36 pp | MoE |
| Renewable Energy Share in Mix | <2% | ≥40% | +38 pp | MoE |
| Geothermal Generation | ~0 MW | 1,700 MW | +1,700 MW | MoE |
| Solar PV Generation | ~50–100 MW | 715 MW | +615–665 MW | MoE |
| Wind Generation | ~0–50 MW | 500 MW | +450–500 MW | MoE |
| Community Mini-Grids | ~30–50 MW | 300 MW | +250–270 MW | MoE / REA |
| Nuclear Power (Pilot) | 0 MW | 1,000 MW | +1,000 MW | MoE |
| Coal-Fired (Compliant) | ~100–200 MW | 1,000 MW+ | +800–900 MW | MoE |
| New Household Connections | Baseline N/A | 4 million new | +4 million HH | MoE / TANESCO / REA |
| Connection Cost Reduction (Low-Income) | Baseline N/A | 50% reduction | −50% | MoE / TANESCO |
| Rural Substations Installed | Baseline N/A | 100 substations | +100 | TANESCO / MoE |
| Aged Transformers Replaced | Baseline N/A | 70% replaced | −70% aging stock | TANESCO |
| Urban Feeder Upgrades | Baseline N/A | 1,000 km upgraded | +1,000 km | TANESCO |
| SCADA Coverage (Control Centres) | Partial | ≥90% | Substantial expansion | TANESCO / EWURA |
| Grid Code Alignment (SAPP/EAPP) | Partial | ≥70% | +40–60 pp | MoE / EWURA |
| Green Finance Mobilised | Baseline N/A | USD 7 billion | +USD 7bn | MoE / MoF / MDBs |
| Natural Gas Production | 69,538 MMSCF/yr | 90,000 MMSCF/yr | +20,462 MMSCF (+29%) | TPDC / MoE |
| Gas Distribution Network | 177.82 km | 267.00 km | +89.18 km (+50%) | TPDC |
| Gas Share in Electricity Mix | 63% (2024) | 45% | −18 pp (diversification) | MoE / TANESCO |
| Energy Professionals Certified | Baseline N/A | 10,000+ | +10,000 certified | MoE / NESDP |
| Grid Reserve Margin | Baseline N/A | ≥20% | Strategic minimum maintained | TANESCO / EWURA |
| LNG Project (Lindi) | FID near-finalisation | LNG capacity operational | Commercial-scale exports begin | TPDC / GoT |
TICGL Analytical Commentary & Assessment
Independent analysis of FYDP IV energy sector ambition, feasibility, and strategic risks
The following commentary represents TICGL's independent analytical assessment of the key themes, feasibility questions, and strategic risks embedded in FYDP IV's energy programme. This is not a summary of the plan — it is a critical evaluation of where the ambitions are realistic, where they carry elevated execution risk, and what the key variables are that will determine success.
The TANESCO Unbundling — A Critical Reform Gamble
The decision to corporatise and fully unbundle TANESCO into three separate entities (Generation, Transmission, Distribution) by June 2031 is the single most structurally significant energy reform in FYDP IV. While this mirrors successful models in South Africa (Eskom's restructuring), Kenya Power's partial reforms, and the EU energy market liberalisation, it carries substantial execution risk in the Tanzanian context. TANESCO's financial position remains fragile, and the unbundling must be accompanied by tariff reform, workforce restructuring, and creditor arrangements. The establishment of the Independent System and Market Operator (ISMO) as a neutral dispatch authority is critical to ensuring that the post-unbundling market does not replicate the inefficiencies of the current vertically integrated model.
Renewable Energy: From 2% to 40% — The Feasibility Question
FYDP IV targets a leap from less than 2% renewables in the generation mix to 40% by 2031. The primary drivers are geothermal (1,700 MW targeted), solar PV (715 MW), and wind (500 MW). Tanzania's geothermal potential — anchored in the East African Rift System — is genuinely substantial, with studies suggesting 5,000+ MW of exploitable resource. However, geothermal development is capital-intensive and has long lead times: the Olkaria fields in Kenya took over a decade to reach current output. A 1,700 MW geothermal programme from near-zero to commissioning by 2031 is extraordinarily aggressive. Solar and wind targets are more achievable given falling technology costs. The success of the renewable transition will be heavily dependent on the clean energy blended finance facility and the USD 7 billion mobilisation target.
LNG Export (Lindi) — The Flagship Revenue Catalyst
The Lindi LNG project — with a Final Investment Decision reported at advanced stage as of early 2025 — represents the most transformational single investment in Tanzania's energy history. A successful FID will unlock multi-billion USD capital flows into the Lindi corridor, create industrial cluster spillovers (petrochemicals, fertilisers, plastics, ammonia), and position Tanzania as a global LNG exporter. The Plan's ambition to transition Tanzania into a 'regional energy power centre' is substantially dependent on this single project. The concurrent domestic gas strategy — expanding pipeline distribution to 267 km and increasing utilisation capacity from 400 to 800 MMSCFD — ensures that LNG export does not come at the cost of domestic industrialisation.
Rural Electrification — The Hardest Last Mile
Rural electrification remains the most persistent challenge. Despite 90% of villages being on the grid by FYDP III's end, only 36% of rural households are actually electrified — pointing to a critical disconnect between grid proximity and actual connection. FYDP IV's target of 4 million new household connections and a 50% reduction in connection costs for low-income households, combined with performance-based incentives for private developers, represents a sensible multi-channel approach. However, without addressing the underlying affordability constraint — that many rural households cannot afford either the connection fee or ongoing tariffs — grid extension alone will not achieve the 42.8% rural electrification target.
Investment Gap & PPP Imperative
The USD 7 billion green finance target is a floor, not a ceiling, for what will be required to build 11,000 MW of new capacity within 5 years. International benchmarks suggest average energy project costs of USD 1–2 million per MW (depending on technology), implying a total capital requirement of USD 11–22 billion for generation alone — before transmission, distribution, and access investments are added. The private sector, through IPPs, IDNOs, and community energy developers, must be the primary driver of this investment. The PPPC's role in designing and implementing bankable PPP structures for energy — particularly for renewable IPPs, distribution network operators, and mini-grid concessions — will be critical to the success of FYDP IV's energy programme.
TICGL Risk Assessment — FYDP IV Energy Targets
Feasibility rating (1–10) and delivery risk level for each major energy target category
Estimated Capital Requirement vs Green Finance Target
USD billions: FYDP IV green finance target vs estimated total capital need (low & high scenarios)
Scale of the Ambition — A Quadrupling of Capacity in Five Years
The energy sector targets in FYDP IV represent one of the most ambitious infrastructure expansion programmes in Tanzania's post-independence history. The target of 15,000 MW of installed capacity by 2031 — compared to the 4,032 MW baseline — implies a 272% increase in just five years. This is a quadrupling of the country's entire electricity system in a single plan period. For context, Tanzania's entire generation capacity took several decades to reach 4,000 MW. Achieving 15,000 MW by 2031 will require an unprecedented pace of project development, commissioning, and financing — and likely the simultaneous development of 15–20 major energy projects across all technology types.