🛢️ Part of our Oil & Gas Industry Training Series — browse all related courses →
About This Course
The valuation of oil and gas reserves sits at the intersection of petroleum engineering, financial analysis, and regulatory compliance. Whether for corporate reporting, merger and acquisition due diligence, asset impairment testing, or capital allocation decisions, the ability to rigorously assess the economic worth of subsurface hydrocarbon resources is one of the most commercially critical competencies in the energy industry.
This five-day programme provides a comprehensive, practitioner-focused grounding in the financial valuation of oil and gas reserves. Participants explore internationally recognised resource classification systems — including the Society of Petroleum Engineers Petroleum Resources Management System (SPE-PRMS) — and learn how proved, probable, and possible reserve categories translate into balance-sheet and investment value. The course covers the full valuation toolkit: deterministic and probabilistic reserve estimation, discounted cash flow (DCF) analysis, net asset value (NAV) models, risked expected monetary value (EMV), and comparable transaction analysis.
Beyond technical methods, the programme addresses the regulatory and disclosure environment governing reserves reporting under frameworks such as SEC Regulation S-X Rule 4-10, IFRS 6, and the guidelines of the International Valuation Standards Council. Participants also examine the macroeconomic variables — commodity price decks, royalty and fiscal regimes, operating cost structures, and abandonment liabilities — that most significantly drive valuation outcomes in oil and gas.
TrainingComplex has designed this course to be highly practical. Each module combines conceptual instruction with real-world case studies drawn from African, Middle Eastern, and global upstream markets. Participants leave with transferable valuation models, a structured analytical framework, and the professional confidence to defend reserve valuations before boards, auditors, investors, and regulators.
Who Should Attend
- Finance managers and financial analysts working in oil and gas companies or energy-focused investment institutions
- Petroleum engineers and reservoir engineers seeking to develop financial and commercial skills
- Corporate finance professionals advising on upstream mergers, acquisitions, and asset transactions
- Internal auditors and external auditors engaged in reserves reporting and asset impairment reviews
- Investment bankers and equity research analysts covering the energy sector
- Treasury and planning managers responsible for capital allocation in upstream businesses
- Regulators and government officials overseeing petroleum sector fiscal and licensing frameworks
- Senior executives requiring a structured understanding of how hydrocarbon assets are financially assessed
Learning Objectives
- Understand the SPE-PRMS and other international resource classification frameworks and their implications for financial valuation
- Distinguish between proved, probable, and possible reserves and apply appropriate risking factors to each category
- Construct and interpret discounted cash flow models for upstream oil and gas assets, including selection of appropriate discount rates
- Apply net asset value methodology to value exploration and production companies and individual asset portfolios
- Use expected monetary value and decision-tree analysis to evaluate exploration prospects under uncertainty
- Incorporate fiscal regime structures — royalties, production sharing contracts, and tax arrangements — into project economics models
- Interpret commodity price scenarios and apply price deck assumptions consistent with SEC, IFRS, and internal corporate guidance
- Quantify and risk-adjust key value drivers including production profiles, capital expenditure, operating costs, and decommissioning liabilities
- Conduct and interpret comparable transaction and public market multiples analysis for oil and gas asset benchmarking
- Apply IFRS 6 and SEC disclosure rules to reserves reporting and communicate valuation conclusions to financial and technical stakeholders
Course Modules
Module 1: The Oil and Gas Value Chain and the Role of Reserves Valuation
- Overview of upstream, midstream, and downstream sectors and where reserve value is created
- Key stakeholders in reserves valuation: companies, regulators, auditors, investors, and lenders
- The commercial significance of reserves on corporate balance sheets and credit ratings
- Introduction to the valuation framework and how the five-day programme modules interconnect
- How reserves reclassification events — such as field revisions or licence expirations — trigger material financial restatements
- The distinction between value-in-use and transactional value of reserves and why different stakeholders apply different lenses
Module 2: Resource Classification: SPE-PRMS and International Standards
- Architecture of the SPE Petroleum Resources Management System: resources, contingent resources, and reserves
- Proved, probable, and possible reserves (1P, 2P, 3P) definitions and their financial implications
- Comparison of SPE-PRMS with SEC definitions and Canadian NI 51-101 guidelines
- Classification exercises: assigning reserve categories to production, development, and exploration assets
- The role of commerciality and project maturity sub-classes in determining whether contingent resources qualify for reserves booking
- Common classification pitfalls: handling technical and commercial uncertainty simultaneously without double-counting risk
Module 3: Petroleum Geology and Reservoir Engineering Essentials for Valuers
- Key geological and reservoir concepts that drive production forecasting: porosity, permeability, and fluid properties
- Decline curve analysis: exponential, hyperbolic, and harmonic decline models and their application to production profiling
- Material balance and volumetric methods for estimating original hydrocarbons in place
- Interpreting engineering reports and reservoir simulation outputs from a financial valuation perspective
- Recovery factor drivers: the impact of drive mechanism, well spacing, and enhanced recovery schemes on ultimate reserve estimates
- Recognising the limitations and uncertainty ranges inherent in engineering estimates and translating them into valuation risk adjustments
Module 4: Production Profiles, Capital Expenditure, and Operating Cost Modelling
- Building field-level production profiles from engineering data and applying production decline assumptions
- Capital expenditure categories: exploration, appraisal, development drilling, and facilities — timing and phasing
- Operating cost structure in upstream projects: fixed versus variable opex, well interventions, and lifting costs
- Decommissioning and abandonment liability estimation and its integration into project economics
- Handling cost inflation, learning-curve effects, and supply-chain constraints when projecting multi-year capital and operating expenditure
- Treatment of joint-venture cost-sharing arrangements and the valuation implications of carried interests and back-in rights
Module 5: Commodity Price Decks and Macro Assumptions
- Historical and forward oil and gas price dynamics: Brent, WTI, Henry Hub, and African benchmark differentials
- SEC flat-price rules versus forward-curve and internal corporate price deck approaches
- Gas pricing structures: LNG netbacks, domestic gas tariffs, and take-or-pay contract economics
- Sensitivity analysis: constructing price scenario matrices and assessing their impact on reserve value
- Quality and location differentials: how API gravity, sulphur content, and pipeline access premiums or discounts are built into price deck assumptions
- Inflation-adjusting price decks: distinguishing real versus nominal price assumptions and their interaction with cost escalation factors in long-dated models
Module 6: Fiscal Regimes and Their Impact on Project Economics
- Concession systems: royalty-tax structures, allowances, and ring-fencing rules in key producing jurisdictions
- Production sharing contracts: cost recovery, profit oil splits, and government participation mechanics
- Service contracts and hybrid arrangements: economic equivalence and valuation adjustments
- Modelling fiscal terms in a project economics framework and calculating government take versus investor returns
- Stabilisation clauses and renegotiation risk: how changes in host-government fiscal policy are assessed and quantified in project valuations
- Comparing effective tax rates across fiscal regimes and using government-take curves to benchmark competitiveness between jurisdictions
Module 7: Discounted Cash Flow Valuation of Upstream Assets
- Building a full upstream DCF model: revenue, costs, taxes, capital expenditure, and working capital
- Discount rate selection: weighted average cost of capital, risk-free rates, and country risk premiums in emerging markets
- Net present value, internal rate of return, and payback period interpretation for upstream investment decisions
- Common DCF pitfalls in oil and gas: terminal value treatment, long-tail production, and inflation assumptions
- Handling asymmetric cash flow timing: the impact of early heavy capital spend and back-loaded production on NPV sensitivity to discount rate changes
- Incorporating contractual optionality — such as extension clauses, development options, and put rights — into the DCF framework without double-counting flexibility value
Module 8: Net Asset Value Modelling for E&P Companies
- NAV methodology: aggregating risked asset values to derive corporate equity value
- Risking factors for exploration prospects, contingent resources, and development projects
- Treatment of corporate costs, debt, hedges, and financial instruments in NAV models
- NAV per share analysis and reconciliation with market capitalisation in listed E&P company valuation
- Building a multi-asset NAV waterfall: sequencing producing fields, development projects, and exploration upside with consistent risking and discount rate assumptions
- Sensitivity of NAV to key operational assumptions — including first-oil timing, plateau rate, and cost overruns — and how analysts stress-test these in a structured scenario framework
Module 9: Probabilistic Methods and Expected Monetary Value Analysis
- Monte Carlo simulation concepts and their application to reserve volume and cash flow uncertainty
- Expected monetary value: decision-tree construction for exploration and appraisal investment decisions
- Risk-weighted resource aggregation: arithmetic versus statistical summation of 2P reserves across a portfolio
- Portfolio-level risk management: diversification effects and capital allocation under resource uncertainty
- Calibrating input distributions for Monte Carlo models: selecting appropriate probability functions for geological, price, and cost variables using analogues and historical data
- Interpreting and communicating probabilistic output: P10/P50/P90 result profiles, tornado charts, and the translation of simulation results into reserve booking and investment decisions
Module 10: Comparable Transactions, Market Multiples, and Valuation Synthesis
- Upstream M&A transaction analysis: data sources, deal structure, and calculating value per barrel of oil equivalent metrics
- Public market comparables: EV/EBITDA, EV/2P, and price-to-NAV multiples for E&P company benchmarking
- Reconciling DCF, NAV, and market-based valuation conclusions into a defensible overall opinion of value
- Presenting and defending valuation conclusions to boards, auditors, joint-venture partners, and regulatory bodies
- Adjusting transaction comparables for deal-specific factors: control premiums, contingent payments, asset quality differences, and the timing of transactions relative to the commodity price cycle
- Documentation and professional standards for formal reserve valuation opinions: competent person requirements, independence disclosures, and the structure of a valuation report that meets regulatory and lender expectations
Requirements & Prerequisites
Participants should have a working knowledge of financial statements and basic corporate finance concepts such as net present value and discounting. Familiarity with the upstream oil and gas industry — either from an engineering, commercial, or finance perspective — is expected. Prior experience in petroleum engineering or energy-sector investment analysis is advantageous but not mandatory, provided participants meet the financial literacy prerequisite.
Training Methodology
- Instructor-led sessions integrating petroleum engineering concepts with financial modelling theory, anchored to real upstream asset scenarios from Africa, the Middle East, and global markets
- Hands-on DCF and NAV model-building workshops using structured Excel templates that participants adapt to case-study assets and take away for future use
- Reserves classification exercises in which participant teams categorise resource volumes under SPE-PRMS and debate the financial impact of different classification decisions
- Fiscal regime modelling sessions where participants construct production-sharing contract and royalty-tax models and analyse their effect on project economics and asset value
- Comparable transaction analysis workshops using publicly disclosed upstream deal data to derive and apply market multiples
- Group case studies based on real upstream assets — including deepwater, onshore conventional, and East African exploration plays — requiring participants to produce and present a complete valuation
- Structured peer review of valuation outputs, with facilitator-led critique focused on assumption robustness and disclosure-readiness
- Regulatory compliance review sessions examining SEC Rule 4-10, IFRS 6, and auditor expectations, using anonymised audit query examples
Organisational Benefits
- Improved accuracy and consistency in reserves-based financial reporting and balance-sheet disclosures
- Stronger internal capability to evaluate upstream asset acquisitions, disposals, and farm-in opportunities
- Reduced regulatory and audit risk through better alignment with SEC, IFRS, and SPE-PRMS standards
- More rigorous capital allocation decisions supported by robust project economics and risk-adjusted valuations
- Enhanced credibility with investors, lenders, and joint-venture partners through defensible and transparent asset valuations
- Greater cross-functional alignment between technical reservoir teams and finance and commercial departments
- Strengthened due diligence processes for mergers, acquisitions, and licence round evaluations
- Development of a pipeline of commercially literate technical professionals and financially competent energy analysts
Where Is Financial Valuation of Oil and Gas Reserves Training Offered?
This course runs in-person across: Nairobi, Johannesburg, Kigali, Kampala, Abuja, Zanzibar, Dubai, Riyadh, Mombasa, Nakuru, Cape Town, Lagos, Naivasha, Arusha, Dar es Salaam, Accra, Addis Ababa, Pretoria, Kisumu, plus Live Virtual (online) cohorts. Browse live dates for your city below.
Upcoming Schedules
| Location | Format | Dates | Price |
|---|
| Nairobi, Kenya |
In-Person |
5 Oct 2026 – 9 Oct 2026 |
KES 105,000 |
| Johannesburg, South Africa |
In-Person |
5 Oct 2026 – 9 Oct 2026 |
USD 3,500 |
| Kigali, Rwanda |
In-Person |
12 Oct 2026 – 16 Oct 2026 |
USD 1,900 |
| Kampala, Uganda |
In-Person |
12 Oct 2026 – 16 Oct 2026 |
USD 1,900 |
| Live Virtual |
Online |
17 Oct 2026 – 8 Nov 2026 |
KES 80,000 |
| Abuja, Nigeria |
In-Person |
19 Oct 2026 – 23 Oct 2026 |
USD 2,800 |
| Zanzibar, Tanzania |
In-Person |
19 Oct 2026 – 23 Oct 2026 |
USD 2,500 |
| Dubai, United Arab Emirates |
In-Person |
19 Oct 2026 – 23 Oct 2026 |
USD 4,100 |
| Riyadh, Saudi Arabia |
In-Person |
19 Oct 2026 – 23 Oct 2026 |
USD 4,500 |
| Mombasa, Kenya |
In-Person |
19 Oct 2026 – 23 Oct 2026 |
KES 120,000 |
| Nakuru, Kenya |
In-Person |
19 Oct 2026 – 23 Oct 2026 |
KES 120,000 |
| Cape Town, South Africa |
In-Person |
19 Oct 2026 – 23 Oct 2026 |
USD 3,800 |
| Lagos, Nigeria |
In-Person |
19 Oct 2026 – 23 Oct 2026 |
USD 2,500 |
| Naivasha, Kenya |
In-Person |
19 Oct 2026 – 23 Oct 2026 |
KES 115,000 |
| Arusha, Tanzania |
In-Person |
26 Oct 2026 – 30 Oct 2026 |
USD 2,100 |
+234 more dates — view live schedule →
Frequently Asked Questions
Do I need to be a petroleum engineer to benefit from this course?
No — the course is designed for both finance professionals and technical staff. Petroleum engineering concepts are explained from first principles specifically to support financial analysis, so participants from a finance or investment background can follow the content without prior engineering training.
Will participants build actual financial models during the course?
Yes. Hands-on DCF and NAV model-building workshops are central to the programme, using structured Excel templates and real-world case study data. Participants take these templates away for use in their own organisations after the course.
Which regulatory frameworks does the course cover?
The course covers the SPE-PRMS resource classification system, SEC Regulation S-X Rule 4-10 reserves disclosure requirements, and IFRS 6 (Exploration for and Evaluation of Mineral Resources), giving participants a broad understanding of the major reporting environments relevant to oil and gas companies.
Is a certificate issued upon completion?
Yes. Participants who attend the full five-day programme and complete the course exercises receive a TrainingComplex Certificate of Completion in Financial Valuation of Oil and Gas Reserves, which can be used to support continuing professional development records.
What should I bring or prepare before attending?
Participants should bring a laptop with Microsoft Excel installed, as the modelling workshops require hands-on spreadsheet work. Reviewing your organisation's most recent reserves report or asset valuation summary beforehand — if accessible — will help contextualise the course material to your day-to-day role.
