AFRICA OIL CORP.  
REPORT TO  
SHAREHOLDERS  
FOR THE YEAR ENDED DECEMBER 31, 2022  
AFRICAOILCORP.COM  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
MANAGEMENT’S DISCUSSION AND ANALYSIS  
The Management’s Discussion and Analysis (“MD&A”) focuses on significant factors that have affected the Company during the year  
ended December 31, 2022, and such factors that may affect its future performance. To better understand the MD&A, it should be read  
in conjunction with the Company’s audited consolidated financial statements for the years ended December 31, 2022, and 2021, and  
related notes thereto.  
The financial information in this MD&A is derived from the Company’s audited consolidated financial statements which have been  
prepared in US dollars, in accordance with IFRS as issued by the International Accounting Standards Board.  
This MD&A was reviewed and approved by the Board of Directors. The effective date of this MD&A is February 27, 2023.  
Additional information about the Company and its business activities is available on the Company’s website at www.africaoilcorp.com  
and on SEDAR at www.sedar.com.  
PROFILE AND STRATEGY  
AOC is a Canadian upstream oil and gas company with producing and development assets in deep-water Nigeria, and development  
assets in Kenya. The Company also has a portfolio of exploration/appraisal assets in Namibia, Nigeria, South Africa and Kenya. The  
Company holds its interests through direct ownership interests in concessions and through its shareholdings in investee companies,  
including Prime, Impact, Africa Energy and Eco.  
AOC’s long-term plan is to deliver sustainable shareholder value through the development and production associated with its existing  
asset portfolio, accretive acquisitions, exploration, and monetizing value from its shareholdings in its investee companies. Africa Oil  
will maintain its primary focus on its Nigerian and Namibian Orange Basin assets and continues to work on optimizing and unlocking  
shareholder value in its other assets.  
The Company is a unique investment opportunity for its exposure to the Venus light oil and associated gas discovery offshore Namibia,  
as it is the only publicly listed independent oil and gas company with an interest in this field. The Venus discovery, together with the  
Graff discovery on a neighbouring block (the Company has no interest in Graff) announced in 2022, have opened a new petroleum  
province in the Orange Basin with significant upside potential. Venus and Graff discoveries support the exploration case for Block  
3B/4B, which is operated by the Company with a 20% WI, and Impact’s Orange Basin Deep Block, both located in Orange Basin and  
on trend with Venus and Graff discoveries.  
AOC’s potentially high impact appraisal and exploration catalysts are complemented by its production and cash flowing assets in  
Nigeria, which it holds through its 50% shareholding in Prime. Prime is a Nigeria-focused company with interests in OML’s 127 and  
130 and accounts for all of AOC’s reserves and production. The Company’s management expect that infill drilling on the currently  
producing fields and the development of oil and gas discoveries in Prime’s portfolio provide scope for ongoing value creation and that  
the OML 127 and OML 130 assets provide the Company with a long life-cycle cash flowing asset base to support its business objectives  
over the long term.  
The Company has delivered on its stated objective of implementing shareholder return programs, having instituted a dividend policy  
in February 2022 and a share buyback program in September 2022. These programs were delivered following consistent positive  
financial results for the Company, its strengthening cash position and stable business outlook. In 2022, the Board of Directors approved  
an annual dividend of $0.05 per share paid in 2 instalments in March 2022 and September 2022 and a Normal Course Issuer Bid (share  
buyback) program of up to CAD 95 million or a maximum of 40,482,356 common shares. On 27 February 2023, the Board of Directors  
have approved a semi-annual dividend of $0.025 per share payable in March 2023.  
The Company continues to pursue an accretive acquisition-led strategy to purchase producing assets, primarily in West Africa, while  
ensuring the target has competitive metrics to complement the Company’s existing low cost, high return portfolio. The Company may  
also pursue infrastructure-led exploration activities, such as the recently announced PSC’s in Equatorial Guinea, where high quality  
prospects are near existing infrastructure that can support fast-track developments in case of successful discoveries.  
PAGE 2  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
HIGHLIGHTS AND OUTLOOK  
2022 AND POST PERIOD HIGHLIGHTS  
The Company received five dividends totaling $250.0 million in 2022 from its shareholding in Prime, including one dividend of $37.5  
million in Q4 2022.  
Cash and cash equivalents at December 31, 2022, of $199.7 million (at December 31, 2021 - $58.9 million), and an undrawn  
corporate loan facility of $100.0 million.  
The Company launched a Normal Course Issuer Bid (share buyback) program on September 27, 2022. Since September 27, 2022,  
until February 24, 2023, a total of 20.2 million Africa Oil common shares have been repurchased, at a cost of $44.8 million and 20.2  
million shares have been cancelled.  
On February 27, 2023, the Company announced a semi-annual dividend of $0.025 per share (approximately $11.6 million) to be  
declared and paid at the end of March 2023.  
During 2022 the Company returned approximately $63.3 million to its shareholders through the share buyback program and the  
dividend policy.  
WI 2P Reserves of 55.6 MMboe at December 31, 2022, net to the Company’s 50% shareholding in Prime. Entitlement 2P Reserves of  
63.9 Mmboe at December 31, 2022, net to the Company’s 50% shareholding.  
Full-year 2022 production rates are in line with the mid-point of 2022 Management Guidance range. Prime recorded an average  
daily WI production of approximately 23,500 boepd and net entitlement production of 25,600 boepd, in each case net to Africa Oil’s  
50% shareholding. These compare with mid-range of 2022 Management Guidance figures of 24,000 boepd and 25,000 boepd for  
WI and net entitlement production, respectively.  
High impact appraisal drilling on Venus to commence imminently. Infill development drilling on Egina and Akpo commenced on  
February 22, 2022.  
In 2022, the Company recognized an impairment to its Kenyan intangible exploration assets of $170.6 million (2021 – nil) due to  
continuing delays and uncertainties to the farm out process and the path to FID.  
On February 20, 2023, the Company announced that it had signed two PSC’s with the Republic of Equatorial Guinea for offshore  
Blocks EG-18 and EG-31, subject to ratification by the local authorities. The Company will hold an 80% percent operated interest,  
subject to back in rights, in each block and presents a potential low cost, low risk development opportunity.  
PRIME HIGHLIGHTS  
Selected Prime results net to the Company’s 50% shareholding:  
»
In Q4 2022 and 2022, revenue of $146.0 million and $723.2 million respectively (Q4 2021 and 2021 - $153.9 million and $610.2  
million respectively). Revenue has increased in 2022 due to higher realized oil price of $84.5/bbl compared to 2021 (2021 - $59.3/  
bbl);  
»
»
Repaid $192.3 million in principal repayments on its RBL and PXF facilities and also drew $75.0 million of its PXF Facility in 2022,  
significantly deleveraging its balance sheet;  
Cash position of $165.9 million and debt balance of $391.2 million at December 31, 2022; Robust Net Debt to EBITDAX for the twelve  
months ended December 31, 2022, of 0.4x (twelve months ended December 31, 2021 – 0.4x) (1)  
;
»
»
Combined with AOC cash and no debt, results in a net debt position of $25.6 million (December 31, 2021 - $190.6 million net debt);  
Average daily WI production of 21,300 boepd and economic entitlement production of 23,500 boepd (81% light and medium crude  
oil and 19% conventional natural gas) in Q4 2022 (Q4 2021 – 26,500 boepd and 28,500 boepd respectively);  
»
»
»
Average daily WI production of 23,500 boepd and economic entitlement production of 25,600 boepd (82% light and medium crude  
oil and 18% conventional natural gas) in 2022 (2021 – 27,400 boepd and 29,700 boepd respectively);  
In Q4 2022 and 2022, EBITDAX of $140.7 million and $600.5 million respectively (Q4 2021 and 2021 - $163.4 million and $654.5  
million respectively) (1)  
;
In Q4 2022 and 2022, cash generated from operating activities before working capital of $58.5 million and $250.5 million respectively  
(Q4 2021 and 2021 - $74.4 million and $536.2 million respectively)(1). 2022 has decreased primarily from additional tax payments of  
$148.5 million and in 2021 a net $152.5 million was received by Prime relating to the Agbami Securitization Agreement deposit; and  
»
Prime and its partners are continuing the work for the early renewal of OML 130 license, which accounts for most of Prime’s production,  
reserves and economic value; however, the process has taken longer than expected due to the critical Presidential election period in  
Nigeria.  
(1) Definitions and reconciliations to the non-GAAP measures are provided on page 14.  
PAGE 3  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
HIGHLIGHTS AND OUTLOOK - CONTINUED  
OUTLOOK  
The Company’s debt-free balance sheet, its share of Prime’s cash flows and access to debt funding on competitive terms, supports a  
range of opportunities for the Company to achieve accretive growth and create shareholder value.  
Nigeria  
The year-end (“YE”) 2022 reserves determination has delivered an after-tax Proved plus Probable reserves (“2P”) NPV(10) valuation of  
$1,232.0 million (YE’21: $1,444.0 million). YE’22 WI and net entitlement 2P reserves of 55.6 MMboe (YE’21: 72.8 MMboe) and 63.9  
MMboe (YE’21: 82.1 MMboe), respectively.  
Lower 2P WI reserves compared with the previous year primarily due to 2022 WI production of 8.7 MMboe and technical revision  
of 8.4 MMboe. The technical revision is mostly due to a reduction in the expected ultimate recovery of the Egina field following the  
incorporation of production performance and the results of the 4D seismic processed during 2022.  
OML 130 drilling campaign for 2023 commenced on February 22, 2022, with the spud of the first infill well on the Egina oil field. This  
is the first well in a multi-well program that is planned for up to 9 wells on Egina and Akpo in the license area. This is the first major  
multi-well drilling campaign since AOC acquired a 50% shareholding in Prime and is aimed at arresting the production decline. The  
campaign is expected to last for most of 2023.  
Prime and its upstream partners are currently working on the early conversion to the new PIA terms of the OML 127 license. It is  
expected that OML 130 early renewal, which accounts for most of the reserves, production and value in Prime’s portfolio can be  
delivered by H1 2023, although a successful outcome on this timeline can’t be guaranteed. It is further expected that a successful early  
renewal of OML 130 could provide the basis for concurrent refinancing of Prime’s RBL and PXF debt, that in turn could support Prime  
increasing cash available for distributions to its shareholders, including Africa Oil, or re-investments in the near term.  
Early renewal of OML 130 could also facilitate the final investment decision for the Preowei oil discovery development project. Preowei  
oil field is to the north of Egina FPSO and is a low-risk development opportunity through a satellite subsea tie-back project to the Egina  
FPSO.  
Venus Appraisal and Venus Extension Exploration Campaign  
Management believe that the most impactful catalysts for the Company in 2023 are the Venus appraisal drilling results from Block  
2913B and follow-on exploration on Block 2912, both located offshore Namibia. A multi-well program in Namibia due to commence  
imminently, targeting up to four wells (including the re-entry of the Venus-1X discovery well, in Block 2913B), to appraise the Venus  
discovery and to investigate a potential westerly extension of Venus, the Nara prospect on Block 2912. AOC has an interest in this  
program through its 30.9% shareholding in Impact.  
Appraisal of Venus Discovery in Block 2913B (PEL 56)  
Drilling of Venus-1A, the first appraisal well on the Venus discovery, located approximately 13km to the north of the Venus-1X discovery  
well, is expected to spud imminently, using the Tungsten Explorer drillship. The Deepsea Mira semi-submersible drilling rig will then  
be used to conduct a drill stem test at this location. The Deepsea Mira will then re-enter the Venus-1X well and conduct a flow test. The  
objective of this program is to further evaluate reservoir and deliver dynamic data.  
Impact holds a 20% WI in PEL 56, which is operated by TotalEnergies who holds a 40% WI. QatarEnergy and NAMCOR respectively hold  
a 30% and 10% WI in PEL 56. The Company’s effective interest is 6.2%.  
Exploration and Potential Appraisal of Block 2912 (PEL 91)  
Block 2912 may contain a highly material extension of the Venus field. Operations by TotalEnergies during 2023, on behalf of the JV,  
are designed to drill an exploration well and, if successful, test this potential extension of the Venus accumulation into Block 2912 and  
provide an understanding of the structure and reservoir quality.  
TotalEnergies is expected to commence drilling operations in Block 2912 during mid-2023. Exploration well Nara-1X will be drilled and  
flow tested by the Tungsten Explorer and, if successful, an appraisal well, Nara-1A, will then be drilled and flow tested.  
Impact holds an 18.89% WI in PEL 91, which is also operated by TotalEnergies who holds a 37.78% WI. QatarEnergy and NAMCOR  
respectively hold 28.33% and 15% WI in PEL 91. The Company’s effective interest is 5.8%.  
All drilling and flow test operations are expected to be completed by end of 2023.  
Block 3B/4B, South Africa  
The Company has a 20% operated interest in Block 3B/4B offshore South Africa. This block is on trend with Venus and Graff oil  
discoveries (the Company has no interest in Graff) in the Orange Basin. The application to extend the Block 3B/4B license and to move  
into the first extension period of 2 years was approved on October 27, 2022. The Company is also continuing its technical studies on  
Block 3B/4B with the aim of maturing exploration prospects for possible future drilling.  
The Company and its JV partners are progressing plans to conduct a two-well campaign on Block 3B/4B and are in discussions with  
various potential partners to farm out up to a 55% gross working interest in the Block. The JV Partners have selected a leading South  
African environmental consulting firm to conduct a comprehensive Environmental and Social Impact Assessment (ESIA) process in  
preparation for permitting and drilling activity on the Block.  
PAGE 4  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
HIGHLIGHTS AND OUTLOOK - CONTINUED  
Kenya  
In 2021, the Company and its partners initiated a farmout process for Project Oil Kenya. A successful farmout is viewed by the Company  
as a critical step towards the FID for Project Oil Kenya being achieved and is viewed as a condition to FID. Discussions with the  
interested parties have taken longer than expected and there is no guarantee that the Company can successfully conclude a farmout  
to new strategic partner(s) on favorable terms. As a consequence of this increased uncertainty on a farm-out and FID, the Company has  
impaired the value of Project Oil Kenya by $170.6 million.  
2023 MANAGEMENT GUIDANCE  
The Company’s 2023 production will be contributed solely by its 50% shareholding in Prime. The 2023 Management Guidance  
includes WI production guidance range of 18,500 – 21,500 boepd and net entitlement production range of 20,500 – 23,500 boepd  
with approximately 82% expected to be light and medium crude oil and 18% conventional natural gas.  
Net entitlement production estimate is based on a 2023 average Brent price of $80.9/bbl being the average of the Brent forward  
curves between November 15, 2022, and January 15, 2023. Net entitlement production is calculated using the economic interest  
methodology and includes cost recovery oil, tax oil and profit oil and is different from WI production that is calculated based on project  
volumes multiplied by Prime’s effective WI.  
Prime is expected to sell three cargoes during Q1 2023. The first cargo of the year was sold at spot with the second and third cargoes  
sold with an average fixed Dated Brent price of $76.1/bbl. Prime has 6 cargoes, scheduled between April and September 2023 with an  
average trigger price of $70.0/bbl. None of these triggers have been reached as of the effective date of this MD&A. The actual sales  
price will include a quality and logistic price adjustment which means the final realized price will be different to the trigger price. See  
page 14 for further details on the crude marketing strategy.  
Based on the above production and cargo lifting ranges and Prime’s current 2023 forward sales contracts schedule, the Company’s  
management estimate Prime to generate cash flow from operations(1) of approximately $250.0 - $330.0 million net to the Company’s  
50% shareholding.  
Any dividends(2) received by the Company from Prime’s operating cash flows and cash on hand will be subject to Prime’s capital  
investment and financing cashflows, including Prime’s RBL and PXF interest payments and principal amortization. Net to the Company’s  
50% shareholding, Prime’s 2023 capital investment is expected to be in the range of $80.0 - $100.0 million. Prime had a cash and cash  
equivalents balance of $165.9 million net to the Company’s 50% shareholding at December 31, 2022  
2023 SUMMARY OF MANAGEMENT GUIDANCE AND 2022 ACTUALS  
2023 Guidance  
2022 Actuals  
Prime, net to AOC’s 50% shareholding:  
WI production (boepd)  
18,500 – 21,500  
20,500 – 23,500  
$250.0 – $330.0  
$80.0 - $100.0  
23,500  
25,600  
$250.5  
$28.4  
Economic entitlement production (boepd)  
Cash flow from operations(1) (million)  
Capital investment (million)  
(1) Cash flow from operations before working capital adjustments.  
(2) Prime does not pay dividends to its shareholders, including the Company, on a fixed pre-determined schedule. Previous number of  
dividends and their amounts should not be taken as a guide for future dividends to be received by the Company. Any dividends received  
by the Company from Prime’s operating cash flows will be subject to Prime’s capital investment and financing cashflows, including payments  
of Prime’s RBL principal amortization, which are subject to semi-annual RBL redeterminations.  
PAGE 5  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
THE COMPANY’S SHAREHOLDING AND WORKING  
INTERESTS  
The Company’s material interests, and material exploration partnership interests are summarized in the following table:  
Africa Oil’s Shareholding in Prime Oil & Gas Coöperatief U.A. (50%)  
Country  
Concession  
License renewal  
Working Interests  
Prime  
Chevron Corporation  
Famfa Oil  
8%  
32%  
60% (carried)  
OML 127  
December 13, 2024 (1)  
NIGERIA  
Prime  
TotalEnergies  
SAPETRO  
16%  
24%  
10% (carried)  
OML 130 – PSA (2)  
February 28, 2025 (1)  
Africa Oil’s Direct Working Interests (3)  
Country  
Concession  
License renewal  
Working Interests  
AOC  
TotalEnergies  
Tullow (Operator)  
25%  
25%  
50%  
Block 13T  
December 31, 2021(4)  
AOC  
TotalEnergies  
Tullow (Operator)  
25%  
25%  
50%  
KENYA  
Block 10BB  
Block 10BA  
Block 3B/4B  
December 31, 2021(4)  
April 22, 2023(5)  
AOC  
TotalEnergies  
Tullow (Operator)  
25%  
25%  
50%  
AOC (Operator)  
Azinam  
Ricocure (Pty) Ltd  
20%  
26%  
54%  
SOUTH AFRICA  
October 26, 2024(6)  
EG-18  
EG-31  
AOC (Operator)  
GEPetrol  
80%  
20%  
EQUATORIAL  
GUINEA  
(7)  
(1) In accordance with the PIA, renewal shall be granted for 20 years if the lessee has paid all rent and royalties due and has otherwise performed  
all its obligations under the lease. Management believes that this will be renewed, in common with other licenses. The PIA includes the  
provision for leases to be converted earlier than their license renewal date.  
(2) 50% of the production from OML 130 is covered by a PSA, in which Prime owns a 32% WI. Prime’s net WI in OML 130 is therefore 16%.  
(3) Net WI are subject to back-in rights or carried WI, if any, of the respective governments or national oil companies of the host governments.  
(4) The licenses were extended to December 31, 2021, and required that the JV partners submit an FDP. The FDP was submitted in December  
2021 and is now subject to governmental review, during which time the license is retained in full force and effect. The JV partners expect the  
license to be renewed once the review is complete.  
(5) 10BA was included in the E&A plan, submitted as part of the Block 10BB/13T FDP.  
(6) The application to extend the Block 3B/4B license and to move into the first extension period of 2 years was approved on October 27, 2022.  
(7) The initial exploration phase was signed on February 17, 2023, pending government ratification, for an initial period of three years.  
Information on the Company’s equity interests in Africa Energy, Eco and Impact is included in ‘Equity Investments in Associates’ on  
page 16.  
PAGE 6  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
BUSINESS UPDATE  
The economic environment for oil producers became more volatile in 2022 mainly due to the Russian invasion of Ukraine. The Brent oil  
price fluctuated significantly in 2022 with the average Brent oil price being approximately $100.9/bbl in 2022, rising from an average of  
$70.5/bbl in 2021. The invasion led to a number of countries placing sanctions on Russian companies and individuals, including oil and  
gas producers. This led to concerns about supply in the short term with the expectation that demand will continue to recover towards  
pre-pandemic levels in 2023. However, global cost inflation and economic recession concerns continue to highlight demand side risks  
that have also contributed to oil price volatility.  
During 2022, Nigeria’s economic activity and growth slowed on the back of declining oil production and softening non-oil economic  
activity. According to the World Bank, real GDP rose by 3.1 per cent year-on-year compared to the annual population growth of 2.6  
per cent. Nigeria’s inflation significantly increased to 21.1 per cent year-on-year in October 2022, increasing fiscal pressure on the  
government with surging subsidy costs. Despite higher oil revenues due to higher oil prices, the country’s official reserves have fallen  
pressuring the Naira, Nigeria’s currency, and business confidence. These fiscal and economic pressures have resulted in downgrading  
of Nigeria’s rating, most recently in January 2023 by Moody’s.  
The business environment for Nigerian oil and gas industry in 2022 was dominated by the new PIA, that was enacted into law in  
2021. The new regulatory and fiscal framework provided by the PIA is expected to provide a more stable investment outlook for the  
Nigerian upstream sector. The provisions in the PIA also allow for voluntary early conversion of the existing licenses, which could be  
accompanied by the renewal of licenses.  
As has become customary in Nigeria since 2019, the 2023 annual budget for Nigeria has been accompanied by a proposed Finance Act  
that support the revenue needs indicated in the budget. In line with that, in late December 2022, both chambers of Nigeria’s National  
Assembly passed the annual Finance Bill for 2023, which includes proposed changes to several different tax laws, including laws that  
can affect directly or indirectly the oil and gas industry. It is understood that the Finance Bill, which was passed on to the Presidential  
Office for its final ascension, has been returned to the National Assembly for further consultation and deliberation. Considering the  
recent Presidential and National Assembly elections and the transition to a new government, the timing for the final passage of the  
Finance Bill and its provisions, including changes that could be relevant to the oil and gas industry are uncertain. If there are adverse  
consequences to the oil and gas industry, this could cause further delay to the conversion of OML 127 and early renewal of OML 130.  
Nigeria’s general election took place on February 25, 2023 to elect the President and Vice President and members of the Senate and  
House of Representatives.  
SHAREHOLDER RETURNS  
The Company instituted a shareholder capital return program in 2022, in the form of payment of semi-annual dividends and share buy  
backs following consistent positive results for the Company and a strong cash position.  
The Company launched a Normal Course Issuer Bid (share buyback) program on September 27, 2022. Since that date, until February  
24, 2023, a total of 20.2 million Africa Oil common shares have been repurchased under the share repurchase program through the  
facilities of the TSX, Nasdaq Stockholm and/or alternative Canadian trading systems. A maximum of 40,482,356 Africa Oil common  
shares may be repurchased under the share buyback program over a period of twelve months ending September 26, 2023, or until  
such earlier date as the share repurchase program is completed or terminated by the Company.  
On February 28, 2022, the Board of Directors approved an initial aggregate annual dividend of $0.05 per share (approximately $23.8  
million) and paid $0.025 per share ($11.9 million) in both Q1 2022 and Q3 2022 in line with the minimum annual dividend target.  
On February 27, 2023, the Company announced it will pay a semi-annual dividend of $0.025 per share (approximately $11.6 million)  
in March 2023. The Board of Directors view the 2023 annual distribution to be prudent with due consideration for the acquisition-led  
business strategy and the priority of maintaining a strong balance sheet in a range of market scenarios.  
EQUITY INVESTMENT IN PRIME – NIGERIA  
The Company’s 50% equity interest in Prime is accounted for as an investment in joint venture under the equity method on the Balance  
Sheet. The Company records a 50% share of Prime’s net income or loss as well as a 50% share of its other comprehensive income or  
loss in the period in the Consolidated Statement of Net (Loss)/ Income and Other Comprehensive (Loss)/ Income. Dividends received  
are disclosed as a cash flow from investing activities in the Consolidated Statement of Cash Flows.  
The main assets of Prime are an indirect 8% WI in OML 127 and an indirect 16% WI in OML 130. OML 127 is operated by affiliates of  
Chevron and covers part of the producing Agbami field. OML 130 is operated by affiliates of TotalEnergies and contains the producing  
Akpo and Egina fields. The three fields in these two OMLs are located over 100 km offshore Nigeria. All three fields have high quality  
reservoirs and produce light to medium sweet crude oil through FPSO facilities. Akpo and Egina also export associated gas which feeds  
into the Nigerian liquified natural gas plant, whilst Agbami associated gas is mostly reinjected.  
All amounts included in the narrative discussions below are net to the Company’s 50% shareholding in Prime, unless otherwise noted.  
PAGE 7  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
BUSINESS UPDATE - CONTINUED  
Production and Operations  
Production Metrics – rounded  
Three months ended  
Year ended  
December 31,  
December 31,  
December 31,  
2022  
December 31,  
2021  
Unit  
2022  
2021  
Total gross field production (1)  
boepd  
323,400  
408,100  
363,700  
426,000  
Net to AOC’s 50% shareholding:  
Average daily WI production (1)  
Average daily entitlement production (1)  
Oil volumes sold  
boepd  
boepd  
MMbbl  
bcf  
21,300  
23,500  
1.4  
26,500  
28,500  
2.0  
23,500  
25,600  
7.4  
27,400  
29,700  
8.5  
Gas volumes sold  
2.5  
2.6  
10.3  
10.3  
Oil/gas percentage split  
%
81%/19%  
83%/17%  
82%/18%  
84%/16%  
(1) The Q4 2021 and 2021 comparative figures have been revised to ensure comparability and consistency of calculation as a result of a change  
in the conversion factor used in converting gas production in mmscfpd to boepd.  
The full year production output was marginally below the midpoint of the management guidance range for WI production (22,500 –  
25,500 boepd) and slightly above the midpoint for economic entitlement production (23,000 – 27,000 boepd). Q4 2022 gross field  
production was lower than Q4 2021, primarily as a result of expected natural reservoir decline and a planned maintenance outage at  
Agbami.  
The Egina and Akpo infill drilling program, which was initially expected to commence in 2022, commenced on February 22, 2023.  
Between 4 and 6 development wells were initially expected to be drilled in OML 130 during 2022, these wells will now be drilled during  
2023.  
Net entitlement production is calculated using the economic interest methodology and includes cost recovery oil, tax oil and profit oil.  
It differs from WI production that is calculated based on field volumes multiplied by Prime’s effective WI in each license. The cargoes  
lifted by Prime and described below represent Prime’s share of cost oil, profit oil and part of income tax oil. The remaining part of  
income tax oil and royalties are either lifted and sold by the operator or paid in cash, to settle the tax and royalty obligations to the  
Nigerian state. From May 2022, Prime has been lifting its share of tax oil and paying PPT in cash for OML 130. Aggregate oil equivalent  
production data comprises of light and medium crude oil and conventional natural gas production net to Prime’s WI in Agbami, Akpo  
and Egina fields. These production rates only include sold gas volumes and not those volumes used for fuel, reinjected or flared.  
In Q4 2022, Prime was allocated 3 oil liftings with total sales volume of approximately 2.88 million barrels or 1.44 million barrels net  
to the Company’s 50% shareholding at an average realized oil price of $96.0/bbl. In Q4 2021, Prime was allocated 4 oil liftings with  
total sales volume of approximately 4.04 million barrels or 2.02 million barrels net to the Company’s 50% shareholding at an average  
realized oil price of $62.1/bbl.  
In 2022, Prime was allocated 15 oil liftings with a total sales volume of approximately 14.86 million barrels or 7.43 million barrels net  
to the Company’s 50% shareholding at an average realized oil price of $84.5/bbl. In 2021, Prime was allocated 17 oil liftings with total  
sales volume of 17.00 million barrels or 8.50 million barrels net to the Company’s 50% shareholding at an average realized oil price of  
$59.3/bbl.  
Financial  
Prime’s financial information is presented in note 5 of the financial statements on a 100% basis, with a reconciliation to the Company’s  
50% share of Prime’s net assets and net income. In Q4 2022 and 2022, the share of profit from the 50% investment in Prime was $2.9  
million and $146.6 million respectively (Q4 2021 and 2021 - $56.1 million and $224.4 million respectively). The share of profit from the  
50% investment in Prime for Q4 2022 has been impacted by an impairment of $41.2 million net to AOC, recognized by Prime. As at  
December 31, 2022, the Company’s investment in Prime was $513.7 million (as at December 31, 2021 - $617.1 million).  
All amounts presented and discussed below are net to AOC’s 50% shareholding in Prime (unless otherwise stated) to reflect AOC’s 50%  
shareholding in Prime.  
PAGE 8  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
BUSINESS UPDATE - CONTINUED  
Financial Metrics  
Three months ended  
Year ended  
December 31, December 31, December 31, December 31,  
Net to AOC’s 50% shareholding:  
Unit  
2022  
2021  
2022  
2021  
Total revenues  
$’m  
146.0  
153.9  
723.2  
610.2  
Cost of Sales (1)  
Gross profit  
Opex/boe (2,3)  
$’m  
$’m  
41.5  
104.5  
10.0  
63.7  
90.2  
8.8  
278.2  
445.0  
8.3  
271.0  
339.2  
7.6  
$/boe  
Cash (used in)/ generated from operating  
activities(4)  
Free cash flow/boe (1,3)  
$’m  
(13.9)  
(7.7)  
60.6  
28.5  
294.8  
32.2  
526.7  
33.0  
$/boe  
Tax  
$’m  
$’m  
$’m  
$’m  
$’m  
48.4  
10.1  
57.4  
10.0  
242.8  
28.4  
230.0  
25.3  
Capex  
Dividends paid  
Cash and cash equivalents  
Loans and borrowings  
37.5  
50.0  
250.0  
165.9  
391.2  
200.0  
258.9  
508.4  
165.9  
391.2  
258.9  
508.4  
(1) Given the nature of Prime’s operations in terms of oil cargo liftings and the variability in their frequency from one quarter to next, the  
non-cash accounting treatment of underlift/overlift and the timing between recording revenues and receipts of sales cash, leads to high  
variability in Prime’s quarterly financial metrics. Please refer to the commentary in the rest of this section for the specific details of this  
period’s changes relative to corresponding historical period.  
(2) Opex represents production costs presented on Prime’s Statement of Net Income and Other Comprehensive Income in note 5 to the  
financial statements.  
(3) Boe is calculated on an entitlement basis. Definitions and reconciliations to these non-GAAP measures are provided on pages 11 and 12.  
(4) Cash generated from operating activities is lower in 2022 compared to 2021 as $305.0 million was received by Prime relating to the Agbami  
Securitization Agreement deposit.  
Prime recognized an impairment of $82.3 million to its oil and gas interests primarily from a reduction in the expected ultimate recovery  
of the Egina field following the incorporation of the results of the 4D seismic acquired in late 2021 as well as an increase in the discount  
rate.  
Revenues  
Three months ended  
Year ended  
December 31, December 31, December 31,  
December 31,  
2021  
Unit  
$’m  
2022  
2021  
2022  
Per Prime’s financial statements  
Total revenue  
291.8  
307.8  
1,446.3  
1,220.3  
Net to AOC’s 50% shareholding:  
Oil revenue  
$’m  
$’m  
138.7  
5.0  
125.4  
5.8  
627.7  
20.3  
54.8  
20.4  
723.2  
84.5  
7.4  
503.5  
49.4  
41.9  
15.4  
610.2  
59.3  
8.5  
Gas revenue  
PPT revenue  
$’m  
(1.4)  
3.7  
18.5  
4.2  
Royalties  
$’m  
Total revenue  
$’m  
146.0  
96.0  
1.4  
153.9  
62.1  
2.0  
Realized oil prices(1)  
Oil volumes sold  
Realized gas prices  
Gas volumes sold  
$/bbl  
MMbbl  
$/bcf  
Bcf  
2.0  
2.2  
2.0  
4.8  
2.5  
2.6  
10.3  
10.3  
(1) Realized oil prices might be different to values calculated from the table above due to roundings.  
PAGE 9  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
BUSINESS UPDATE - CONTINUED  
The increase in oil sales revenue in Q4 2022 was mainly due higher realized price of $96.0/bbl in Q4 2022 compared with $62.1/bbl in  
Q4 2021 partly offset by lower sales volumes. The increase in oil sales revenue in 2022 was also mainly due to a higher realized price  
of $84.5/bbl in 2022 compared to $59.3/bbl in 2021 despite lower volumes sold.  
Gas sales revenue was recognized for the first time in Q3 2021, due to the signing of the OML 130 Gas Sales and Purchase Agreement  
in July 2021, which resolved historical gas sales from July 2018. As the terms for sale were only agreed in July 2021, Prime did not have  
the right to recognize gas revenue until then. Revenue from gas sales in 2021 included an additional $29.2 million recognized, relating  
to the period from July 2018 to December 2020. Revenue from gas sales in Q4 2022 and 2022 totaled $5.0 million and $20.3 million  
respectively (Q4 2021 and 2021 – $5.8 million and $49.4 million).  
PPT revenue is revenue recognized for tax oil, being Prime’s share of entitlement production that is sold by the operators to settle its  
tax obligation to the Nigerian state. As the tax oil lifted by the operator on behalf of Prime is sold to 3rd party customers and proceeds  
are used to settle Prime’s tax liabilities, this share of PPT is considered to be within the scope of IFRS 15, ‘Revenue from contracts with  
customers’. Consequently, this portion of income tax is presented gross in revenue and offset in current income tax expense. From May  
2022, Prime has been lifting its share of tax oil and paying PPT in cash for OML 130, therefore such revenue is already accounted in the  
oil volumes sold by Prime.  
Agbami royalties are presented gross in both revenue and cost of sales.  
Cost of sales  
Three months ended  
December 31,  
Year ended  
December 31,  
December 31,  
December 31,  
$’m  
2022  
2021  
2022  
2021  
Per Prime’s financial statements  
Total cost of sales  
82.9  
127.4  
556.3  
542.1  
Net to AOC’s 50% shareholding:  
DD&A  
34.5  
22.1  
(23.4)  
8.3  
37.3  
23.0  
(4.9)  
8.3  
131.4  
77.1  
151.7  
82.5  
Production costs  
Movements on overlift/underlift balances  
Royalties – oil and gas  
Total cost of sales  
23.4  
(16.0)  
52.8  
46.3  
41.5  
63.7  
278.2  
271.0  
Cost of sales has decreased in Q4 2022 compared with Q4 2021. This is mainly due a movement from a net overlift position in Q3 2022  
to a net underlift position at Q4 2022 which has resulted in a credit in cost of sales and there was a small increase in the net underlift  
position in Q4 2021. The overlift/ underlift position represents Prime’s excess of liftings over its entitlement share of production.  
The Q4 2022 position has also been valued at a higher price compared with Q4 2021.  
Cost of sales has increased slightly in 2022, compared with 2021, mainly due to a decrease in the net underlift position in 2022  
compared to an increase in the net underlift position in 2021, representing Prime’s excess of liftings over its entitlement share of  
production. The overlifted position has also been valued at a higher price compared with 2021. This was offset by a reduction in the  
DD&A charge, which was mainly due to a change in the estimates in 2P reserves and economic cut-off dates.  
Royalties were first recognized in Q3 2021 from the Akpo field for the period between November 2019 and December 31, 2021,  
implemented under the Deepwater Production Act and reaffirmed in the PIA. There are no royalties from the Egina field as it has been  
granted a royalty holiday until January 2024, being 5 years after first oil.  
Royalties of $84.0 million gross relating to Akpo have been reconciled with the NUPRC to November 2022. Payments were made in  
Q4 2022 for the period to November 2022. The unpaid amount related to December 2022, has been included in working capital as a  
current liability. The Akpo royalties were not previously accrued due to uncertainties over payment which were resolved when the PIA  
was enacted on August 16, 2021.  
PAGE 10  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
BUSINESS UPDATE - CONTINUED  
Opex/boe  
Opex/boe is a non-GAAP measure which represents production costs on a per barrel of oil equivalent basis (using entitlement  
production). This allows the Company to better analyze performance against prior periods on a comparable basis. The most direct  
financial statement measure is production costs, disclosed in note 5 to the financial statements. Net entitlement production is  
calculated using the economic interest methodology and includes cost recovery oil, tax oil, profit oil and royalties and is different from  
WI production that is calculated based on project volumes multiplied by Prime’s effective WI in each license.  
Three months ended  
December 31, December 31,  
Year ended  
December 31,  
December 31,  
Unit  
$’m  
2022  
2021  
2022  
2021  
Per Prime’s financial statements  
Production costs  
44.1  
46.0  
154.1  
165.1  
Net to AOC’s 50% shareholding:  
Production costs  
$’m  
22.1  
2.2  
23.0  
2.6  
77.1  
9.3  
82.5  
10.8  
7.6  
Entitlement production  
Opex/boe (1)  
MMboe  
$/boe  
10.0  
8.8  
8.3  
(1) The Q4 2021 and 2021 comparative figures have been revised to ensure comparability and consistency of calculation as a result of a change in  
the conversion factor used in converting gas production in mmscfpd to boepd.  
Production costs are largely stable when comparing Q4 2022 and Q4 2021.  
Production costs have decreased in 2022 compared to 2021 with the operators continuing to implement cost reduction measures and  
in 2021, production costs included the execution of planned maintenance activities in Agbami which are not included in 2022.  
The increase in opex/boe in Q4 2022 compared to Q4 2021 is primarily due to a decrease in entitlement production in Q4 2022. There  
was a smaller increase in opex/boe in 2022 compared to 2021 due to a decrease in entitlement production offset by a reduction in  
production costs.  
Cash generated from operating activities  
Three months ended  
December 31, December 31,  
Year ended  
December 31, December 31,  
$’m  
2022  
2021  
2022  
2021  
Per Prime’s financial statements  
Cash (used in)/ generated from operating activities (1)  
(27.7)  
121.2  
589.5  
1,053.4  
Net to AOC’s 50% shareholding:  
Cash (used in)/ generated from operating activities  
(13.9)  
60.6  
294.8  
526.7  
Working capital adjustments included in cash generated  
from operating activities  
Changes in trade and other receivables  
Changes in over/underlift balances  
(2.6)  
(23.4)  
(46.4)  
(72.4)  
58.5  
(77.7)  
(4.9)  
18.7  
23.4  
2.2  
(77.6)  
(16.0)  
84.1  
Changes in other working capital balances  
Total working capital adjustments  
68.8  
(13.8)  
74.4  
44.3  
250.5  
(9.5)  
Cash generated from operating activities before working capital  
536.2  
(1) The Q4 2021 comparative figures have been revised to ensure comparability and consistency of calculation as a result of a change in the  
classification of items between of cash generated from operating activities, cash used in investing activities and cash used in financing activities.  
Cash flow from operating activities is negative in Q4 2022 primarily due to a retrospective payment of $59.0m for the period from  
November 2019 to November 2022 related to royalties recognized on sales made from the Akpo field. Royalties of $42.0 million were  
reconciled with the NUPRC to Q1 2022 and estimated alongside the operator to November 2022. The related Q3 2022 accrual has  
been released in changes in other working capital balances. Tax payments were also higher in Q4 2022 compared to Q4 2021.  
Cash generated from operating activities has decreased in 2022 from 2021 due to a $152.5 million one off cash receipt in Q2 2021 from  
Equinor for its portion of the security deposit as stipulated within the Securitization Agreement as well as a decrease in income from  
investment tax credits, withholding tax incurred on an intergroup dividend declared included in other operating costs and higher tax  
payments offset by higher revenues generated in the period.  
PAGE 11  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
BUSINESS UPDATE - CONTINUED  
FCF and FCF/boe  
FCF before working capital adjustments is a non-GAAP measure. This measure represents cash generated after costs, and is a measure  
commonly used to assess the Company’s profitability. A reconciliation from total cash flow (a GAAP measure) to FCF (a non-GAAP  
measure) is shown below:  
Three months ended  
Year ended  
December 31,  
December 31,  
December 31,  
December 31,  
Unit  
2022  
2021  
2022  
2021  
Per Prime’s financial statements  
Total cash flow  
$’m  
$’m  
$’m  
$’m  
(287.6)  
75.0  
178.7  
-
28.1  
100.0  
20.1  
-
(186.2)  
500.0  
285.8  
-
286.5  
400.0  
Add back dividends  
Add back debt service costs (1)  
Less security deposit received (2)  
330.9  
(305.0)  
FCF  
$’m  
(33.9)  
148.2  
599.6  
712.4  
Net to AOC’s 50% shareholding:  
FCF  
$’m  
(17.0)  
2.2  
74.1  
2.6  
299.8  
9.3  
356.2  
10.8  
Entitlement production  
FCF/boe (3)  
MMboe  
$/boe  
(7.7)  
28.5  
32.2  
33.0  
(1) Debt service costs comprise interest payments, repayments and drawdowns of third-party borrowings.  
(2) The receipt of the deposit has been excluded from the calculation of free cash flow as any imbalance payments under the terms of any  
future agreement among the Agbami parties will be set-off against this security deposit. See Agbami Securitization Agreement on page 15  
for further details of this security deposit.  
(3) The Q4 2021 and 2021 comparative figures have been revised to ensure comparability and consistency of calculation as a result of a change  
in the conversion factor used in converting gas production in mmscfpd to boepd. The adjustment removing the working capital adjustments  
has been removed from the calculation to make FCF/boe in line with common presentation in the sector.  
The figures used in the explanations for movements period on period below are based on Prime’s gross balances per the financial  
statements.  
FCF is negative in Q4 2022 primarily due to a retrospective payment of $118.0m for the period from November 2019 to November  
2022 related to royalties recognized on sales made from the Akpo field. Royalties of $84.0 million were reconciled with the NUPRC to  
Q1 2022 and estimated alongside the operator to November 2022. Tax payments were also higher in Q4 2022 compared to Q4 2021.  
FCF has decreased in 2022 compared 2021 primarily from an increase in cost of sales of $7.2 million, a decrease in other operating  
income of $242.6 million (primarily investment tax credits) in 2022 from 2021 and an increase to other operating costs of $36.5 million  
offset by revenues being approximately $226.0 million higher, as a result of higher realized prices of $84.5/bbl compared with $59.3/  
bbl, despite lower crude liftings.  
FCF/boe is a non-GAAP ratio which represents FCF on a per barrel of oil equivalent basis using entitlement production which allows  
the Company to better analyze performance against prior periods on a comparable basis. Net entitlement production is calculated  
using the economic interest methodology and includes cost recovery oil, tax oil and profit oil and is different from WI production that  
is calculated based on project volumes multiplied by Prime’s effective WI in each license.  
PAGE 12  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
BUSINESS UPDATE - CONTINUED  
Tax  
The gross tax expense in Q4 2022 and 2022 was $96.8 million and $485.6 million respectively (Q4 2021 and 2021 - $114.8 million and  
$460.0 million). The tax expense is made up of the following items.  
Three months ended  
Year ended  
December 31,  
December 31,  
December 31,  
December 31,  
2021  
$’m  
2022  
2021  
2022  
Per Prime’s financial statements  
Petroleum Profit Tax  
Deferred tax income  
Education tax  
143.1  
(50.3)  
2.6  
116.5  
(15.8)  
7.4  
590.0  
(157.4)  
41.7  
439.2  
(34.5)  
27.7  
Corporate income tax  
Total  
1.4  
6.7  
11.3  
27.6  
96.8  
114.8  
485.6  
460.0  
Net to AOC’s 50% shareholding:  
Total  
48.4  
57.4  
242.8  
230.0  
Petroleum Profits Tax is a tax on the income of companies engaged in upstream petroleum operations. The PPT rate for petroleum  
operations under production sharing contracts with the Nigerian National Petroleum Corporation (NNPC) is 50%. In Q1 2022, Prime  
exhausted its unused investment tax credit pool and lower additional credits have since been generated on capital expenditure  
incurred on qualifying assets.  
Education tax is imposed on every Nigerian company at a rate of 2.5% of the assessable profit in the period.  
Capital expenditure  
Capital expenditures in Q4 2022 and 2022 of $10.1 million and $28.4 million respectively related to development well planning, testing  
and pigging. Expenditures in Q4 2021 and 2021 of $10.0 million and $25.3 million respectively related to drilling and additions to  
facilities and included drilling activities on the Akpo field.  
Dividends paid  
In Q4 2022, Prime distributed one dividend payment totaling $75.0 million with a net payment to the Company of $37.5 million (Q4  
2021 – one dividend with a net payment to the company of $50.0 million). In 2022, Prime distributed five dividend payments totaling  
$500.0 million with a net payment to the Company of $250.0 million (2021 – four dividends with a net payment to the company of  
$200.0 million).  
In the period from completion of the Prime acquisition to the date of this MD&A, Prime has distributed dividend payments totaling  
$1,300.0 million gross with a net payment to the Company of $650.0 million related to its 50% interest, covering 125% of the closing  
cash payment in under three years.  
Cash and Borrowing and Net Debt to EBITDAX  
At December 31, 2022, Prime had a gross cash balance of $331.7 million and debt of $782.3 million (as at December 31, 2021 - $517.9  
million of cash and debt of $1,016.8 million). Net to AOC’s 50% shareholding, Prime has $165.9 million of cash and debt of $391.2  
million (as at December 31, 2021 - $258.9 million of cash and debt of $508.4 million).  
The debt outstanding has decreased slightly following an extra drawdown on the PXF Facility of $150.0 million offset by gross  
repayments on the RBL and PXF Facility of $384.5 million. Net to AOC’s 50% shareholding, the overall debt reduced by $117.3 million  
during 2022.  
At December 31, 2022, Prime has a Net Debt of $450.6 million (as at December 31, 2021 – Net Debt of $498.9 million) and a Net  
Debt/EBITDAX of 0.4x for the twelve months ended December 31, 2022, (0.4x for the twelve months ended December 31, 2021) with  
Net Debt and EBITDAX both decreasing by similar proportions. The strength of this ratio demonstrates the low leverage within Prime  
compared with industry peers. This strong Net Debt/EBITDAX ratio, combined with the full repayment of the Company’s Corporate  
Facility in 2021 means the Company and Prime are well placed to raise more debt in the future if required. Net Debt/EBITDAX is a non-  
GAAP measure, and a reconciliation is performed on page 14.  
PAGE 13  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
BUSINESS UPDATE - CONTINUED  
Reconciliation of Prime’s EBITDAX and Net Debt/EBITDAX  
EBITDAX (non-GAAP measure): This is used as a performance measure to understand the financial performance from Prime’s business  
operations without including the effects of the capital structure, tax rates, DD&A, impairment and exploration expenses. A reconciliation  
from total profit (a GAAP measure) to EBITDAX (a non-GAAP measure) is shown below.  
Net Debt (non-GAAP measure): Net Debt is calculated as loans and borrowings less cash and cash equivalents.  
Net Debt/EBITDAX (non-GAAP ratio): Net Debt divided by EBITDAX and is a measure of the leverage.  
Three months ended  
Twelve months ended  
December 31,  
December 31,  
December 31,  
December 31,  
$’m  
2022  
2021  
2022  
2021  
Per Prime’s financial statements  
Total profit  
11.9  
119.5  
299.4  
441.6  
Add back:  
Tax  
96.8  
22.8  
114.8  
16.8  
(0.3)  
74.6  
1.3  
485.6  
74.6  
460.0  
100.4  
(0.4)  
Finance costs  
Finance income  
DD&A and Impairment  
Exploration expenses  
EBITDAX  
(2.3)  
(6.5)  
151.2  
0.9  
345.0  
2.8  
303.4  
3.9  
281.3  
326.7  
1,200.9  
1,308.9  
Loans and borrowings  
Cash and cash equivalents  
Net Debt  
(782.3)  
331.7  
(450.6)  
0.4  
(1,016.8)  
517.9  
(498.9)  
0.4  
Net Debt/ EBITDAX  
Net to AOC’s 50% shareholding:  
Net Debt  
(225.3)  
600.5  
0.4  
(249.5)  
654.5  
0.4  
EBITDAX  
Net Debt/ EBITDAX  
AOC Net Cash  
199.7  
58.9  
AOC Net Cash/(Debt) inclusive of  
50% Prime Net Debt  
(25.6)  
(190.6)  
Forward Sales and Revised Crude Oil Marketing  
Prior to May 2022, the cargoes that were allocated to Prime, accounted for Prime’s cost oil and profit oil shares and excluded its tax  
oil and royalty barrels, which were sold by the operator on behalf of Prime, in order to settle Prime’s tax and royalty obligations. From  
May 2022, Prime has been lifting its share of tax oil and paying PPT in cash for OML 130. The timing and number of cargo liftings can  
vary based on number of factors including reservoir performance, actual realized oil price, capex, opex, underlift/overlift positions and  
marine logistics. The revenue numbers reported for Prime include cost oil, profit oil, tax oil and royalty contributions.  
Prime continues to use physical forward sales contracts for the marketing and sale of its lifted entitlement production, to manage  
commodity price risk and ensure stability in cash flows in line with the shareholders agreement. The average cargo lifted is for 1 million  
barrels of oil.  
Prime historically fixed the Dated Brent component of the sales price in its forward sales contracts ahead of the lifting date, based on  
the forward curve price for the expected lifting date. During Q2 2022, Prime’s Supervisory Board approved a revised crude marketing  
strategy that maintains the 50% - 70% coverage target for the next 12-months’ scheduled cargoes but no longer fixes the Dated Brent  
component for all of the sales ahead of the lifting date, instead uses a trigger price mechanism. Under this new strategy, Prime gives an  
irrevocable instruction to an offtaker to fix the Dated Brent component of a cargo when the forward curve price goes below a certain  
trigger based on a percentage of the Brent forward curve (at the time when the instruction was given) for the month of the expected  
lifting. Otherwise, the cargo is sold on a spot basis. The current percentage used by Prime to set these thresholds is around 80% of the  
Brent forward curve and it can be altered depending on, among other factors, the shape of the forward curve.  
For example, one cargo expected in April 2023 was set with a trigger of $70.0/bbl. This means that if the forward curve drops below  
$70.0/bbl for the month of the forecast cargo, the Dated Brent component of the forward sale price would be locked in. If the forward  
curve does not drop below $70.0/bbl up to 31 days before the cargo is lifted, then Prime will sell on a spot basis. This policy allows  
Prime to retain price upside, while securing a minimum oil price for 50% to 70% of its oil entitlement in a falling oil price environment.  
PAGE 14  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
BUSINESS UPDATE - CONTINUED  
Oil sales for the year were comprised of the following:  
2022  
Q2  
Oil Sales  
Unit  
Q1  
Q3  
Q4  
Total  
15  
Number of cargoes lifted  
5
3
4
3
Of which:  
Sold forward with a fixed Dated Brent price (1)  
5
-
3
-
3
1
4
-
3
3
11  
4
Sold forward with a trigger price  
5
3
15  
Gross crude oil sales  
Quantity in Mboe  
Mboe  
$/ bbl  
$/ bbl  
4,984.0  
68.8  
3,032.0  
77.1  
3,955.5  
101.5  
99.1  
2,887.5 14,859.0  
Average sales price  
96.0  
88.3  
84.5  
99.9  
Average Bloomberg Dated Brent for the period  
99.5  
112.9  
(1) One of these cargoes was sold in late May for a July delivery with a fixed Dated Brent component that came in line with the spot price.  
Based on the table above, oil revenue net to AOC’s 50% shareholding in Prime amounted to $627.7 million for the year ended 31  
December 2022 and $138.7 million for the three months period ended 31 December 2022.  
The lifting of OML 130 tax oil from May 2022 resulted in Prime being allocated more cargoes during 2022 than originally anticipated at  
start of 2022. Africa Oil had guided to 11-13 cargoes being allocated to Prime during the year; however, Prime was eventually allocated  
and sold a total of 15 cargoes. Most of these additional barrels were lifted during H2 2022. This resulted in changes in Prime’s lifting  
schedule which are now reflected in the table above.  
In the Q3 2022 Report to Shareholders, it was stated that one out of the four cargos lifted during Q3 2022 was at a fixed Dated Brent  
price. After further review it was determined that it was actually three out of the four cargos lifted during Q3 2022 that had a fixed Dated  
Brent price with one of these cargoes being sold in late May for a July delivery with a fixed Dated Brent component that came in line  
with the spot price. This has no impact on the financial statements.  
Prime is expected to sell three cargoes during Q1 2023. The first cargo of the year was sold at spot with the second and third cargoes  
sold with an average fixed Dated Brent price of $76.1/bbl. Prime has 6 cargoes, scheduled between April and September 2023 with an  
average trigger price of $70.0/bbl. None of these triggers have been reached as of the effective date of this MD&A.  
Agbami Securitization Agreement  
OnJune 25,2021,Prime signed a SecuritizationAgreement with Equinor and Chevron,whereby Equinor agreed to pay a security deposit  
to the two other partners to secure future payments due under that Securitization Agreement, pending a comprehensive resolution  
being reached among all unit parties in respect of the tract participation in the Agbami field. In accordance with the Securitization  
Agreement, on June 29, 2021, Prime received from Equinor its portion of the security deposit in the form of a cash payment of $305.0  
million gross. A provision for the full cash payment has been recorded within Prime’s accounts to reflect the mechanism pursuant to  
which any such imbalance payments due from Equinor to Prime under the terms of any future agreement among the Agbami parties  
will be set off against this security deposit. The parties will continue ongoing discussions in an attempt to seek final resolution of the  
formal redetermination of the Agbami tract participation.  
Petroleum Industry Act  
On August 16, 2021, the Nigerian President signed the Petroleum Industry Bill into law as the Petroleum Industry Act 2021. The PIA will  
change the terms that are applied to Prime’s licenses on renewal, or on early conversion and renewal. A number of amendments to  
fiscal terms have been made and analysis is ongoing but are expected to be positive overall to Prime when the licenses are renewed.  
Other non-GAAP measures related to Prime  
This MD&A includes non-GAAP measures, non-GAAP ratios and supplementary financial measures as further described herein. These  
non-GAAP figures do not have a standardized meaning prescribed by IFRS and, therefore, may not be comparable with the calculation  
of similar measures by other companies. The Company believes that the presentation of these non-GAAP figures provides useful  
information to investors and shareholders as the measures provide increased transparency and the ability to better analyze performance  
against prior periods on a comparable basis.  
PAGE 15  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
BUSINESS UPDATE - CONTINUED  
THE SOUTH LOKICHAR DEVELOPMENT PROJECT (BLOCKS 10BB AND 13T) AND  
EXPLORATION BLOCK 10BA  
The Company has a 25% WI in Blocks 10BB and 13T (before Government’s back-in rights) with Tullow Oil plc (50% and Operator) and  
TotalEnergies (25%) holding the remaining interests.  
In December 2021, as per the license extension requirements provided by the GoK in September 2020, the Project Oil Kenya JV  
Partners submitted an FDP for the 10BB and 13T licenses. The submission of the FDP is followed by a period of review by the GoK,  
during which time the licenses remain in good standing. In Q2 2022, the 10BA license was extended to April 22, 2023.  
The additions to intangible exploration assets during the year include exploration expenditures incurred directly relating to the projects,  
the recognition of a liability for the ongoing court case in Kenya following the decision by the High Court of Kenya, a provision of $10.0  
million related to unresolved Kenya joint venture matters and also included the recognition of a provision for costs to decommission  
and restore the exploration and development sites in Kenya.  
The Company determined that there was an indicator of impairment for the Project Oil Kenya CGU. The Company and its JV partners  
are actively seeking strategic partners for the project and it is intended that a strategic partner will be secured ahead of FID. As there  
have been continuing delays and uncertainties to the farm out process, the Company considered this an indicator for impairment and  
therefore the Company has recorded an impairment charge of $170.6 million.  
The Company and its JV Partners are actively seeking strategic partners for the project. It is intended that a strategic partner will be  
secured ahead of the FID.  
BLOCK 3B/4B – SOUTH AFRICA  
The Company farmed in to Block 3B/4B, offshore South Africa, in July 2019. The Company holds a 20% participating interest and  
operatorship. The initial results from the Venus discovery, along with the Graff discovery, has opened a new petroleum province in the  
Orange Basin with significant upside potential. These discoveries support the exploration case for Block 3B/4B.  
The 2D and 3D seismic data previously acquired in the Block is being evaluated by the JV partners and has formed the basis for the  
initial period work program along with other regional and technical studies. The joint venture is reprocessing 3D seismic data in the  
areas of interest.  
The application to extend the Block 3B/4B license and to move into the first extension period of 2 years was approved on October 27,  
2022. The work commitment for this extension period includes the completion of 2,020 square kilometres of 3D seismic reprocessing  
and integration of well and seismic data.  
BLOCKS EG-31 AND EG-18 – EQUATORIAL GUINEA  
The Company announced on February 20, 2023, that it has signed two PSC’s with the Republic of Equatorial Guinea for offshore Blocks  
EG-18 and EG-31. These PSCs are subject to ratification by the country’s government. Africa Oil will hold eighty per cent (80%) operated  
interests in each block with the balance to be held by GEPetrol, the national oil company of Equatorial Guinea. GEPetrol has the option  
of acquiring an additional fifteen percent (15%) participating interest in each block. Both blocks are covered by 3D seismic data and the  
total minimum work commitment for both blocks in the initial exploration periods is a combined total of USD 7 million, with no drilling  
commitment.  
In Block EG-31 the Company has identified several gas-prone prospects in shallow water depths of less than 80 meters and close to  
existing infrastructure, including the offshore Alba gas field and the onshore Punta Europa Liquefied Natural Gas (“LNG”) Terminal.  
In Block EG-18 the Company has identified a potentially large and highly prospective basin floor fan prospect of Cretaceous age, that  
is similar to those within the Company’s exploration portfolio in Namibia and South Africa.  
The Company will be focused on maturing the identified exploration targets with the aim of attracting strategic partners ahead of  
exploration drilling in the next few years.  
EQUITY INVESTMENTS IN ASSOCIATES  
The Company holds equity investments in three oil and gas companies, which provides exposure to several high-impact exploration  
drilling prospects in South Africa, Namibia, and Guyana.  
The Company held the following equity investments in associates as of December 31, 2022:  
Africa Energy  
1,407,812,249  
276,982,414  
-
Eco  
365,682,014  
39,898,763  
15,042,981  
54,941,744  
Impact (1)  
931,523,968  
255,629,487  
31,936,373  
287,565,860  
Issued and Outstanding  
Shares held by AOC at January 1, 2022  
Shares acquired in the period  
Shares held by AOC at December 31, 2022  
276,982,414  
AOC’s holding (%) – December 31 2022  
AOC’s holding (%) – December 31, 2021  
Share price on December 31, 2022  
19.67%  
19.80%  
15.02%  
19.96%  
30.87%  
30.88%  
CAD $0.19  
0.74  
CAD $0.30  
0.74  
-
-
Exchange rate to USD on December 31, 2022  
(1) Impact is a privately held UK company and no share price is available.  
PAGE 16  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
BUSINESS UPDATE - CONTINUED  
Impact  
Impact is a private UK oil and gas exploration company with assets located offshore Namibia, South Africa and West Africa. The  
Company’s ownership interest is approximately 30.9% at December 31, 2022.  
On February 24, 2022, Impact announced that the Venus-1X exploration well in Block 2913B, offshore Namibia was drilled to a total  
depth of 6,296 meters by the operator TotalEnergies. The operator reported discovery of a good quality, light oil-bearing sandstone  
reservoir of Lower Cretaceous age, with an estimated 84 meters of net pay. Up to three appraisal wells and a re-entry into Venus-1X  
are being planned, with spud expected in Q1 2023. The operator plans to conduct flow tests on both wells. The JV will also continue  
to progress its exploration activities on Blocks 2913B and neighboring Block 2912, including the acquisition of a 3D seismic survey.  
The Company has an indirect effective interest of approximately 6.2% in Block 2913B through its shareholding in Impact.  
On July 18, 2022, the Company subscribed for 31,936,373 shares in Impact for $19.0 million and following the transaction the Company  
holds 30.9% of the enlarged share capital in Impact.  
Africa Energy  
Africa Energy is an international oil and gas exploration company that holds a 27.5% participating interest in the offshore Exploration  
Right for Block 2B in South Africa, and an effective 4.9% participating interest in the Exploration Right for Block 11B/12B offshore South  
Africa. The Company’s ownership interest is approximately 19.7% at December 31, 2022.  
The Block 11B/12B joint venture is proceeding with development studies and engaging with authorities on gas commercialization  
due to the success of the Brulpadda and Luiperd gas condensate discoveries. The development of Block 11B/12B will have positive  
implications for the South African economy and will be critical in facilitating the country’s energy transition away from coal with a  
domestic natural gas supply.  
Africa Energy previously held a 90% participating interest in Block 2B. On April 20, 2021, Africa Energy closed a farmout transaction  
with Azinam and Panoro to transfer operatorship and an aggregate 62.5% participating interest in the Exploration Right for Block 2B in  
consideration for a carry of exploration costs on the next exploration well, Gazania-1 which was completed as a non-commercial well  
in November 2022. The Block 2B joint venture submitted a Production Right application to the Petroleum Agency of South Africa on  
November 15, 2022. The Gazania-1 well was logged, plugged and abandoned, and the joint venture partners are currently undertaking  
a detailed analysis of the results. Further analysis and integration of the well data will allow the joint venture to determine next steps on  
the block. Africa Energy retains a 27.5% participating interest in Block 2B.  
Eco  
Eco operates and holds WI in four exploration blocks offshore Namibia and two exploration blocks offshore South Africa, and has a  
direct WI and indirect interest in two exploration blocks offshore Guyana. The Company’s ownership interest is approximately 15.0% at  
December 31, 2022.  
Eco has made a number of corporate acquisitions in 2022. In January 2022 Eco purchased approximately 7.35% in JHI who has a  
17.5% WI in the ExxonMobil-operated Canje Block, which is located offshore and north of Eco’s Orinduik Block, and in March 2022 Eco  
acquired 100% of Azinam Group Limited. Key assets acquired are a 50% WI and Operatorship in Block 2B, where Africa Energy and  
Panoro Energy ASA are partners, and a 20% WI in Block 3B/4B where the Company is the Operator and 20% WI partner. Consideration  
for both transactions was made with Eco shares and diluted the Company’s shareholding from 19.7% to approximately 16.3%.  
In Q2 2022, Eco completed two equity raises for a total of $37.8 million which were placed with, or subscribed for by, new and existing  
institutional investors. The Company subscribed for 15,042,981 common shares for a consideration of $5.8 million and following this  
the Company held 16.9% of the enlarged share capital in Eco.  
During June 2022, Eco signed a farmout agreement in which its wholly owned subsidiary Azinam Limited acquired an additional 6.25%  
participating interest in Block 3B/4B for consideration of $10.0 million settled substantially in Eco shares. Eco received TSX Venture  
Exchange approval for the transaction on July 6, 2022. Following the approval of issuance, the Company held 15.9% of the enlarged  
share capital in Eco.  
Since June 27, 2022, Eco cancelled a number of shares and issued shares, in which the Company did not participate, and following this  
the Company held 15.0% of the share capital in Eco.  
On October 4, 2022, Eco commenced operations on the Gazania-1 exploration well using an island innovator semi-submersible drilling  
rig which had arrived at the block. The well was drilled 25km offshore in 150 meters of water and drilled to a depth of approximately  
2,360 meters to target a stacked pay section up dip of the AJ-1 discovery and in the proven oil horizon. The well was plugged and  
abandoned after encountering non-commercial oil shows on November 22, 2022.  
PAGE 17  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
BUSINESS UPDATE - CONTINUED  
ENVIRONMENTAL, SOCIAL AND GOVERNANCE  
The Company is committed to being a full-cycle E&P company that integrates sustainability considerations throughout its decision-  
making and operational management. As a non-operating investor in exploration and production assets, the Company is focused on  
the effective identification and management of risk. The Company selects its operating partners in part on their ability and commitment  
to manage ESG risks effectively. The Company monitors operator performance and works with operators where possible and necessary  
to improve performance. The Company’s role as the custodians of its shareholders’ capital is to ensure robust governance systems are  
in place to deliver our sustainability goals.  
Despite these efforts, a serious incident occurred on May 30, 2022, in Kenya at a Joint Venture location and associated facilities. During  
an operation to dispose of expired explosives, an uncontrolled explosion occurred, resulting in injury to two persons involved in the  
exercise. One of those people later died from his wounds. The other injured party was evacuated to Nairobi for medical treatment and  
has since recovered fully. Africa Oil and the Joint Venture Partners have since paid appropriate compensation under Kenyan law to  
the injured party and the family of the deceased. Africa Oil has participated in both the Operator’s and Police investigations into the  
incident. All non-routine activities at the project were put on hold while the partners take corrective actions to address the factors that  
contributed to this event.  
In order to comply with requirements imposed by IFC, one of the Company’s major shareholders, independent monitoring reviews  
are conducted on a regular basis to assess compliance with IFC Performance Standards. The Q3 2022 IMG Review included a review  
of the fatal incident in Kenya, including two additional recommended corrective actions beyond those identified through the internal  
investigation. All Independent Monitoring Group reports can be found on Africa Oil’s website.  
In Nigeria, two independent assessments of Prime’s Environmental Social Health and Safety performance conducted over Q1-Q3  
2022 confirmed the robustness of Prime’s approach to the management of Environmental, Social, Health and Safety (ESHS) issues.  
Additionally, in Q2 2022, Prime finalized and adopted an ESG strategy aligned with Africa Oil’s ESG governance approach and  
strategic goals. Most notably, the ESG strategy commits Prime to achieve net zero emissions across Scopes 1 and 2 by 2050, with  
provisional interim targets for a 20% reduction by 2025 and 30% reduction by 2030. The interim targets will be confirmed following  
additional detailed technical assessments by and in cooperation with the operators of OML 127 and OML 130. Prime is providing ESG  
performance data to the Company on a quarterly basis and full-year data is presented in the 2022 Sustainability Report, which will be  
released after the 2022 financial statements and will be available on the Company’s website. In addition to providing transparency to  
the Company’s stakeholders, this data enables better engagement with the operating partners around performance and opportunities  
for improvement.  
Prime’s ESG strategy will help to support Africa Oil’s own climate objectives. In 2021, the Company announced its intention to achieve  
carbon neutrality by 2025. This past year, the Company progressed development of a comprehensive Energy Transition Strategy  
including science-based short-, medium- and long-term targets towards net zero across Scope 1 and 2 emissions. The Company  
expects to be in a position to communicate the new strategy in 2023 subject to further detailed assessment.  
Although the company continues to work with operating partners to realize operational reductions, the Company will largely rely on  
carbon offsets to meet our carbon neutrality target. The preference is to invest directly in nature-based carbon removal projects to  
develop a dedicated source of emissions offsets, where the Company has full transparency into and control over the project quality.  
Towards that end, the Company has started work to identify and develop two high-quality emissions offset projects in Kenya that also  
deliver social and environmental benefits.  
Given the early-stage nature of these projects, there is risk they may not progress or deliver the volume of credits required. For that  
reason, the Company continues to screen the market for further opportunities, as well as secure existing credits over-the-counter. As  
a demonstration of our commitment toward carbon neutrality, Africa Oil purchased and retired 26,400 credits in 2022 from a REDD+  
project in Guinea-Bissau at a cost of $500,000, on top of the 30,088 clean cookstove credits purchased and retired in 2021.  
PAGE 18  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
SELECTED ANNUAL INFORMATION  
(Expressed in millions of United States dollars unless otherwise stated)  
December 31,  
December 31,  
2021  
December 31,  
2020  
For the years ended  
2022  
Statement of Net (loss)/ income and Comprehensive (loss)/ income:  
Net (loss)/ income attributable to common shareholders  
(60.3)  
190.7  
(17.6)  
Data per Common Share:  
Basic (loss)/ income per share ($/share)  
Diluted (loss)/ income per share ($/share)  
(0.13)  
(0.13)  
0.40  
0.40  
(0.04)  
(0.04)  
Balance Sheet:  
Working capital  
Total assets  
158.6  
917.7  
42.6  
51.8  
991.6  
35.9  
29.1  
910.5  
143.4  
Long-term liabilities  
In 2022, the Company recorded a net loss attributable to common shareholders of $60.3 million which is a decrease from the income  
recorded in 2021 of $190.7 million as the Company recognized an impairment to its Kenyan intangible exploration assets of $170.6  
million and the Company’s share of profit from Prime reduced by $77.8 million. The reduction in share of profit from Prime was primarily  
from a gross impairment recognized by Prime of $82.3 million to its oil and gas interests which has reduced the Company’s share of  
its result in the joint venture. The net loss in 2022 is primarily made up of income from the Company’s investment in Prime of $146.6  
million and the impairment loss on its Kenyan assets of $170.6 million. In 2021, the Company achieved a record net income attributable  
to common shareholders of $190.7 million. This compared with a net loss of $17.6 million in 2020, due the profits from Prime and  
investments in associates being offset by the recognition of a $215.6 million impairment of intangible exploration assets relating to  
Project Oil Kenya and Block 10BA in 2020. The net income in 2021 is primarily made up of income from the Company’s investment in  
Prime of $224.4 million.  
In 2022, the basic loss and diluted loss per share was $0.13 (2021 – basic earnings and diluted earnings per share of $0.40). The  
decrease in earnings per share for 2022 compared to 2021 is primarily from the impairment of $170.6 million recognized in 2022 which  
was not present in 2021. In 2021, the basic earnings and diluted earnings per share was $0.40 (2020 – basic loss and diluted loss per  
share of $0.04). The value went from a loss to earnings as there was a net loss attributable to common shareholders of $17.6 million in  
2020 as a result of a $215.6 million impairment of intangible exploration assets relating to Project Oil Kenya and Block 10BA, and there  
was a net income attributable to common shareholders of $190.7 million in 2021.  
In 2022, the increase in working capital was driven by an increase in cash balances and the decrease to total assets was driven by the  
impairment to the Kenyan Intangible exploration assets of $170.6 million and a lower carrying value of the Company’s investment in  
Prime as dividends received from Prime were higher than the Company’s share in the result of Prime, partly offset by the higher working  
capital balances. Residual dividends from Prime increased cash on hand in 2022, offset by the instituted shareholder capital return  
program in 2022 and cash injections in Eco and Impact. In 2021, an increase in working capital was driven by an increase in the cash  
balance and an increase to total assets was driven by the increase in cash and an increase in the value of the Company’s investment in  
Prime. In 2021, cash increased as the Corporate Facility was repaid in full on November 30, 2021, and residual dividends received from  
the Company’s investment in Prime resulted in an increase in cash on hand.  
In 2022, long-term liabilities increased primarily from the recognition of a provision for site restoration costs in relation to the Kenyan  
exploration projects. In 2021, long-term liabilities decreased due to the full repayment of the Term Loan and Corporate Facility.  
PAGE 19  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
SUMMARY OF QUARTERLY INFORMATION  
Summarized quarterly results for the past eight quarters are as follows:  
31-Dec  
2022  
30-Sep  
2022  
30-Jun  
2022  
31-Mar  
2022  
31-Dec  
2021  
30-Sep  
2021  
30-Jun  
2021  
31-Mar  
2021  
For the three months ended  
Share of (loss)/ profit from equity  
investments in joint venture and  
associates  
(5.1)  
76.5  
70.6  
13.3  
5.7  
53.7  
61.8  
69.7  
58.5  
47.4  
38.4  
47.9  
Net (loss)/ income attributable to  
common shareholders  
(182.2)  
475,074  
475,074  
45.6  
475,090  
485,113  
54.9  
474,192  
479,611  
38.9  
472,147  
475,011  
Weighted average shares – Basic ‘000  
477,311 477,166  
491,131 490,562  
473,505 473,253  
477,799 476,398  
Weighted average shares  
– Diluted ‘000  
Basic (loss)/ income per share ($)  
Diluted (loss)/ income per share ($)  
(0.39)  
(0.39)  
0.15  
0.14  
0.01  
0.01  
0.10  
0.09  
0.12  
0.12  
0.12  
0.12  
0.08  
0.08  
0.08  
0.08  
SUMMARY OF KEY ITEMS OF FINANCIAL PERFORMANCE IN THE THREE MONTHS AND YEARS ENDED  
DECEMBER 31, 2022, AND DECEMBER 31, 2021  
Three months ended  
Year ended  
December 31, December 31,  
December 31, December 31,  
2022  
(5.1)  
(2.3)  
(2.5)  
2021  
61.8  
(2.8)  
(1.4)  
2022  
138.4  
(6.2)  
2021  
226.9  
(6.3)  
Total operating (loss)/ income  
Salaries and benefits  
Share-based compensation  
(9.5)  
(6.3)  
Professional fees and other general and  
administrative expenses  
(2.1)  
(0.8)  
(11.3)  
(5.4)  
Impairment of intangible exploration assets  
(170.6)  
-
(170.6)  
-
Net operating (loss)/ income  
(182.6)  
56.8  
(59.2)  
208.9  
Total and net operating (loss)/income  
In Q4 2022 and 2022, the Company recognized net operating losses amounting to $182.6 million and $59.2 million respectively (net  
operating income in Q4 2021 and 2021 - $56.8 million and $208.9 million respectively). There is a net operating loss in Q4 2022 and  
2022 as an impairment to the Kenyan intangible exploration assets was recognized and the Company’s share of the result in Prime  
has decreased significantly as a result of an impairment recognized by Prime to its oil and gas properties.  
In Q4 2022 and 2022, included in the Company’s share of profit from equity investments is profit from its 50% investment in Prime of  
$2.9 million and $146.6 million (Q4 2021 and 2021 - $56.1 million and $224.4 million respectively).  
The figures used in the explanations for movements period on period below are based on Prime’s gross balances per the financial  
statements.  
Prime recorded a decrease in revenues of $16.0 million in Q4 2022 compared to Q4 2021, mainly from lower volumes sold  
compared to Q4 2021 despite a higher realized price of $96.0/bbl in Q4 2022 compared with $62.1/bbl in Q4 2021. Prime also  
recorded a decrease in cost of sales of $44.5 million, mainly driven by a higher underlift movement during Q4 2022 compared to Q4  
2021. This resulted in a higher gross profit. There was a decrease in other operating income of $74.2 million, an impairment expense  
of $82.3 million recognized on oil and gas interests, offset against a decrease in the tax expense of $18.0 million. Other operating  
income primarily consists of investment tax credits which can be offset against PPT. Therefore, a decrease in tax credits has also  
resulted in an increase in PPT. This has resulted in Prime’s profit in Q4 2022 decreasing by $107.6 million compared to Q4 2021.  
Prime recorded an increase in revenues of $226.0 million in 2022 compared to 2021, due to higher realized prices of $84.5/bbl  
compared with $59.3/bbl, partly offset by slightly lower crude liftings. Cost of sales increased by $14.2 million mainly from a decrease  
in the net underlift position in 2022 compared to an increase in the net underlift position in 2021 partly offset by lower depletion  
charges in 2022. This resulted in a higher gross profit. There was a decrease in other operating income of $242.6 million, an increase  
in other operating costs of $36.5 million, mainly from withholding tax incurred on an intergroup dividend declared of $33.8 million,  
and an increase to the tax expense in 2022 of $25.6 million, as a result of investment tax credits decreasing. Prime recognized an  
impairment of $82.3 million to its oil and gas interests from a reduction in the expected ultimate recovery of the Egina field following  
the incorporation of the results of the 4D seismic acquired in late 2021 as well as an increase in the discount rate. There has also  
PAGE 20  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
SUMMARY OF QUARTERLY INFORMATION - CONTINUED  
been a decrease in finance costs of $25.8 million as in 2021 there was a loss on derivative financial instruments of $30.6 million which  
Prime did not have in 2022 and also the average carrying value of external borrowings has decreased. This has resulted in Prime’s  
profit 2022 decreasing by $142.2 million compared to 2021.  
Salaries and benefits  
Salaries and benefits have decreased in Q4 2022 compared to Q4 2021 from higher time writing charges in Q4 2022.  
In 2022, salaries and benefits have stayed consistent compared to 2021.  
Share based compensation  
The share-based compensation charge relates to the LTIP and Stock Option Plan.  
There is an increase in the expense in Q4 2022 from Q4 2021 as the share price of the Company was higher in Q4 2022 compared to  
Q4 2021.  
There is an increase in the charge in 2022 compared to 2021 as the Q1 2022 charge was $2.6 million higher than in Q1 2021. This  
was due to a larger number of share units being valued at a higher share price than in Q1 2021.  
Professional fees and other general and administrative expenses  
In Q4 2022 and 2022, the professional fees and other general and administrative expenses were higher compared to Q4 2021 and  
2021 as there was increased expenditure on legal and professional fees relating to corporate development activities.  
Impairment of intangible exploration assets  
In 2022, the Company recorded an impairment to its Kenyan Exploration assets of $170.6 million (2021 – nil).  
The Company determined that there was an indicator of impairment for the Project Oil Kenya CGU. The Company and its JV partners  
are actively seeking strategic partners for the project and it is intended that a strategic partner will be secured ahead of FID. As there  
have been continuing delays and uncertainties to the farm out process, the Company considered this an indicator for impairment and  
therefore the Company has recorded an impairment charge of $170.6 million.  
SUMMARY OF KEY ITEMS OF FINANCIAL POSITION AS AT DECEMBER 31, 2022,  
AND DECEMBER 31, 2021  
December 31,  
2022  
December 31,  
2021  
As at  
Assets  
Equity investment in joint venture  
Equity investments in associates  
Intangible exploration assets  
Cash  
513.7  
137.3  
63.6  
617.1  
120.7  
194.3  
58.9  
199.7  
Liabilities  
Long-term debt  
-
-
Equity investment in joint venture  
As at December 31, 2022, the Company’s investment in Prime was $513.7 million compared to $617.1 million as at December 31,  
2021. The carrying value of the investment increased from the share of Prime’s profit of $146.6 million in 2022, offset by dividends  
received of $250.0 million in 2022.  
Equity investments in associates  
As at December 31, 2022, the Company’s investment in associates was $137.3 million compared to an investment value of $120.7  
million as at December 31, 2021. The increase in the investment is primarily due to additional investments in Eco of $5.8 million and  
Impact of $19.0 million, reduced by a net share of their losses in the period.  
PAGE 21  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
SUMMARY OF QUARTERLY INFORMATION - CONTINUED  
Intangible exploration assets  
The Company’s intangible exploration assets relate to its interests in Blocks 10BB and 13T in Kenya, and Block 3B/4B in South Africa.  
Kenya  
The additions to intangible exploration assets during the year include exploration expenditures incurred directly relating to the  
projects, the recognition of a liability for the ongoing court case in Kenya following the decision by the High Court of Kenya, a  
provision of $10.0 million related to unresolved Kenya joint venture matters and also included the recognition of a provision for costs  
to decommission and restore the exploration and development sites in Kenya.  
The Company’s Kenyan Branch, of its wholly owned subsidiary, Africa Oil Kenya B.V. (“AOKBV”), has been assessed for corporate  
income tax and value added tax by the Kenya Revenue Authority (“KRA”) relating to farmout transactions completed during the  
period 2012 to 2017.  
On April 8, 2020, Africa Oil announced that Kenya Tax Appeals Tribunal (“TAT”) ruled in favour of the Company with regards to the  
CIT assessments and in favour of KRA with regards to the VAT assessments. Subsequently, AOKBV filed an appeal with the High Court  
of Kenya to challenge the VAT decision and KRA filed an appeal in relation to the CIT decision.  
On November 30, 2022, the High Court of Kenya announced its decisions on AOKBV’s and KRA’s Tax Appeal. AOKBV’s appeal with  
regard to the VAT assessment was partly successful and the High Court concluded that AOKBV owes VAT in an amount of Kenyan  
Shillings 2,293,334,065 (approximately US$18.7 million). The KRA’s appeal with regard to the CIT decision was also partly successful  
and the High Court concluded that the KRA was correct to disallow certain costs claimed by AOKBV; however, it is not expected to  
have a material cashflow impact.  
AOKBV maintains its position that the VAT assessment is without merit and has duly filed a Notice of appeal with Kenya’s Court of  
Appeal to challenge the position. The KRA has filed a Notice of Appeal regarding the CIT assessment. There is uncertainty as to the  
final outcome of the ongoing court case and therefore, the final outcome is indeterminable at this time. Although AOKBV is taking  
legal advice on the options available to it in view of this decision, including the option to appeal, a liability has been recognised as at  
December 31, 2022, as a result of the High Court ruling.  
The Company determined that there was an indicator of impairment for the Project Oil Kenya CGU. The Company and its JV partners  
are actively seeking strategic partners for the project and it is intended that a strategic partner will be secured ahead of FID. As there  
have been continuing delays and uncertainties to the farm out process, the Company considered this an indicator for impairment and  
therefore the Company has recorded an impairment charge of $170.6 million.  
South Africa  
The Company holds a 20% participating interest in the Block 3B/4B Exploration Right. In Q4 2022 and 2022, the Company incurred  
$0.2 million and $0.6 million respectively, on Block 3B/4B reevaluating 2D and 3D seismic data previously acquired (Q4 2021 and  
2021 - $0.1 million and $0.4 million respectively).  
Cash  
As at December 31, 2022, the Company had $199.7 million cash on hand, compared with a cash balance of $58.9 million as at  
December 31, 2021. The increase to cash is due to dividends received from Prime in 2022 of $250.0 million offset by the dividend  
payments to shareholders in Q1 2022 and Q3 2022 for $23.8 million, share buybacks under the launched Normal Course Issuer Bid  
amounting to $39.9 million and other corporate costs including additional equity injections into Eco and Impact.  
Long-term debt  
As at December 31, 2022, and December 31, 2021, the Company had no long-term debt following the full repayment of the  
Corporate Facility in November 2021.  
PAGE 22  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
LIQUIDITY AND CAPITAL RESOURCES  
As at December 31, 2022, the Company had cash of $199.7 million and working capital of $158.6 million. The Company’s primary  
source of liquidity is dividends received from Prime. If Prime experiences operational delays, reduced performance or similar adverse  
conditions, or reinvest their free cash flow, the dividends received could be reduced in future periods.  
Corporate Facility  
The Company has an undrawn Corporate Facility arranged in May 2021 for three years. The facility amount is $100.0 million, available  
until May 2023. The Corporate Facility carries interests of 1 month-LIBOR plus a margin of 6.5% in the first year, 7.0% in the second  
year and 7.5% in the third year.  
The principal amounts, if drawn, may not exceed $80.0 million by September 30, 2023, and $50.0 million by February 29, 2024. Any  
loan repayments are calculated to be protective of the Company’s liquidity position. Prior to maturity, repayments under the loan are  
made in the month a dividend is received from Prime. The Company’s loan repayments reduce commensurately with any reduction  
in dividends from Prime. If drawn, the loan principal would be repaid by the lesser of 100% of the dividends received from Prime,  
and of an amount that ensures the Company hold a minimum projected consolidated cash balance in the six months following the  
repayment.  
On October 20, 2022, the Company agreed amendments which will become effective on licence renewal being received on OML  
130. The Corporate Facility will be increased from $100.0 million to $200.0 million and can be drawn until October 20, 2023. The  
maturity date has been extended to October 20, 2025.  
The Corporate Facility is subject to financial and liquidity covenants. The Company has been in compliance with the covenants in the  
three months ended December 31, 2022. The Company has no off-balance sheet arrangements.  
Future Funding Outlook  
Regarding the South Lokichar Basin development, the Company will continue to minimize capital investment until an FDP and  
strategic partner is approved. The Company’s current working capital position may not provide it with sufficient capital resources to  
complete development activities being considered in the South Lokichar Basin in Kenya or to settle its ongoing tax disputes with the  
KRA.  
To nance its future acquisition, exploration, development and operating costs, the Company may require financing from external  
sources, including issuance of new shares, issuance of debt or executing farmout or disposition arrangements. There can be no  
assurance that such financing will be available to the Company or, if available, that it will be offered on terms acceptable to the  
Company.  
The Company believes that its existing cash balances combined with anticipated funds flow from Prime dividends will provide  
sufficient liquidity for the Company to meet its financing, operating and capex commitments as they fall due.  
OUTSTANDING SHARE DATA  
The following table outlines the maximum potential impact of share dilution upon full execution of outstanding convertible  
instruments as at the effective date of the MD&A.  
Common shares outstanding  
462,790,680  
3,000,616  
Outstanding share purchase options  
Outstanding performance share units  
Outstanding restricted share units  
7,641,886  
2,066,248  
Full dilution impact on common shares outstanding  
475,499,430  
PAGE 23  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
RELATED PARTY TRANSACTIONS  
Transactions with Africa Energy:  
As at December 31, 2022, the Company’s ownership interest in Africa Energy is approximately 19.7%.  
Services Agreements:  
Three months ended  
Years ended  
Service  
provider  
December 31, December 31, December 31, December 31,  
Service provided  
2022  
2021  
2022  
2021  
General  
Management and  
Service Agreement  
Administrative  
services provided  
to Africa Energy.  
AOC to  
Africa Energy  
-
-
-
0.1  
Technical and  
administrative  
General Technical  
and Administrative  
Service Agreement (1)  
Africa Energy services relating to its  
0.1  
0.1  
0.4  
0.4  
to AOSAC  
operating interest in  
Block 3B/4B,  
South Africa.  
(1) Contract date July 1, 2020  
In December 2022, the Company signed a Promissory note with Africa Energy, alongside other parties, with a total value of $5.0 million,  
in which the Company agreed to provide $2.0 million. This amount was drawn in December 2022. The note carries interest of 10% from  
drawdown until October 31, 2023, at which time the annual interest rate for any outstanding amount increases to 15%, retrospectively.  
The maturity date of the loan is January 31, 2024.  
Transactions with Eco:  
On June 28, 2021, the Company subscribed for 5,945,913 new common shares at a price of CAD$0.41 per new common share totaling  
$2.0 million and was granted the same number of warrants to acquire common shares at the same price over a two-year period.  
On April 6, 2022, the Company subscribed for 10,178,116 common shares for a consideration of $4.0 million and following this the  
Company held 17.3% of the enlarged share capital in Eco. On June 27, 2022, the Company subscribed for 4,864,865 common shares  
for a consideration of $1.8 million and following TSX Venture Exchange approval the Company held 15.9% of the enlarged share  
capital in Eco.  
As at December 31, 2022, the Company’s ownership interest in Eco is approximately 15.0%.  
Transactions with Impact:  
On July 18, 2022, Impact made an open offer to existing shareholders to raise up to $60.0 million through the issue of ordinary shares.  
The Company subscribed for 31,936,373 shares in Impact for $19.0 million and following the transaction the Company holds 30.9%  
of the enlarged share capital in Impact.  
As at December 31, 2022, the Company’s ownership interest in Impact is approximately 30.9%.  
Remuneration of Directors and Senior Management:  
Remuneration of Non-Executive Directors and Senior Management includes all amounts earned and awarded to the Company’s  
Board of Directors and Senior Management. Senior Management includes the Company’s President and Chief Executive Officer, Chief  
Financial Officer, Chief Operating Officer and Vice President of Exploration.  
Directors’ fees include Board and Committee Chair retainers. Management’s short-term wages and benefits include salary, benefits,  
bonuses and any other cash-based compensation earned or awarded during the year. Share-based compensation includes expenses  
related to the Company’s share purchase option plan as well as the Long-Term Incentive Plan.  
December 31,  
2022  
December 31,  
2021  
For the years ended  
Non-Executive Directors' fees  
0.4  
1.0  
0.4  
0.9  
3.1  
3.4  
7.8  
Non-Executive Directors' share-based compensation  
Managements' short-term wages and benefits  
Managements' share-based compensation  
3.8  
4.8  
10.0  
PAGE 24  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
COMMITMENTS AND CONTINGENCIES  
The following commitments and contingencies are representative of AOC’s net obligations at the effective date of the MD&A.  
PRIME OIL AND GAS COÖPERATIEF U.A:  
Under the Prime Sale and Purchase Agreement completed on January 14, 2020, a deferred payment of $118.0 million, subject to  
adjustment, may be due to the seller contingent upon the timing and final OML 127 tract participation in the Agbami field. The  
signing of the Securitization Agreement by Prime has led to the Company reassessing its view of the likelihood of making a contingent  
consideration payment to the seller. The signing of the Securitization Agreement by Prime does not constitute a redetermination of the  
tract participation and therefore does not trigger the payment of a contingent consideration under the Sale and Purchase Agreement  
but, at the Company’s discretion, could trigger discussions with the seller. The outcome of this process is uncertain. In 2021, the  
Company recorded $32.0 million as contingent consideration and increased the Company’s investment in Prime. As at December 31,  
2022, this remains the best estimate of the most likely outcome.  
KENYA LICENSE COMMITMENTS:  
Under the terms of the Block 10BA PSC, the Company received approval from the Ministry of Petroleum and Mining for the Republic of  
Kenya for an extension to the second additional exploration period to April 26, 2023, allowing time for the joint venture to include and  
align the Block 10BA work program with the proposed FDP for Blocks 10BB and 13T. During the second additional exploration period,  
the Company and its partners are obligated to complete geological and geophysical operations, including either 500 km2 of 2D or  
45 km2 of 3D seismic. Additionally, the Company and its partners are obligated to drill one exploration well. The total minimum gross  
expenditure obligation for the second additional exploration period is $19.0 million. The JV partners have not provided any letters of  
credit or guarantees for this commitment. The Company has presented a plan for exploration and appraisal in Block 10BA in the FDP.  
This drilling plan was formally submitted in December 2021. At December 31, 2022, the Company’s working interest in Block 10BA  
was 25%.  
SOUTH AFRICA LICENSE COMMITMENTS:  
The application to extend the Block 3B/4B license and to move into the first extension period of 2 years was approved on October 27,  
2022. The work commitment for this extension period includes the completion of 2,020 square kilometres of 3D seismic reprocessing  
and integration of well and seismic data. At December 31, 2022, the Company’s WI in Block 3B/4B was 20%.  
CRITICAL ACCOUNTING ESTIMATES  
The Company’s critical accounting estimates are defined as those estimates that have a significant impact on the portrayal of its  
financial position and operations and that require management to make judgements, assumptions and estimates in the application  
of IFRS. Judgements, assumptions and estimates are based on historical experience and other factors that management believes to  
be reasonable under current conditions. As events occur and additional information is obtained, these judgements, assumptions and  
estimates may be subject to change.  
USE OF ESTIMATES  
The preparation of the consolidated financial statements in conformity with IFRS requires management to make estimates and  
assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as at the date of  
the consolidated financial statements, and the reported amounts of revenues and expenses during the reporting period. Such estimates  
include unsettled transactions and events as of the date of the consolidated financial statements. Accordingly, actual results may differ  
from these estimated amounts as future confirming events occur. Significant estimates used in the preparation of the consolidated  
financial statements include, but are not limited to, recovery of exploration costs capitalized in accordance with IFRS, equity method  
accounting, valuation and impairment of equity investments and contingent consideration arising from the acquisition of Prime.  
The Company’ significant accounting policies can be found in the Company’s Consolidated Financial Statements for the year ended  
December 31, 2022.  
INTANGIBLE EXPLORATION ASSETS  
The Company capitalizes costs related to the acquisition of a license interest, directly attributable general and administrative costs,  
expenditures incurred in the process of determining oil and gas exploration targets, and exploration drilling costs. All exploration  
expenditures that related to properties with common geological structures and with shared infrastructure are accumulated together  
within intangible exploration assets. Costs are held un-depleted until such time as the exploration phases on the license area are  
complete or commercially viable reserves have been discovered and extraction of those reserves is determined to be technically  
feasible. The determination that a discovery is commercially viable, and extraction is technically feasible requires judgement.  
Where results of exploration drilling indicate the presence of hydrocarbons which are ultimately not considered commercially viable,  
all related costs are recognized in the Consolidated Statement of Net Income and Comprehensive Income. If commercial reserves  
are established and technical feasibility for extraction demonstrated, then the related capitalized intangible exploration costs are  
transferred into the smallest group of assets that generate cash inflows from continuing use that are largely independent of the cash  
inflows of other assets or groups of assets (CGU) within intangible exploration assets. The allocation of the Company’s assets into CGUs  
requires judgement.  
Intangible exploration assets are assessed for impairment when they are reclassified to property and equipment, and also if facts and  
circumstances suggest that the carrying amount exceeds the recoverable amount.  
PAGE 25  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
CRITICAL ACCOUNTING ESTIMATES - CONTINUED  
The recoverable amount of an asset or a CGU is the greater of its value in use and its fair value less costs of disposal. In assessing  
value in use, the estimated future cash flows are discounted to their present value using a pre-tax discount rate that reflects current  
market assessments of the time value of money and the risks specific to the asset. Value in use is generally computed by reference to  
the present value of the future cash flows expected to be derived from production of proven and probable reserves. In determining  
fair value less costs of disposal, recent market transactions are taken into account, if available. In the absence of such transactions, an  
appropriate valuation model is used.  
The key assumptions the Company uses for estimating future cash flows are the quantity of contingent resources, future commodity  
prices, expected production volumes, future operating and development costs, likelihood of a successful farm out process and  
subsequent timing of FID and discount rate. The estimated useful life of the CGU, the timing of future cash flows and discount rates are  
also important assumptions made by management.  
The changing worldwide demand for energy and the global advancement of alternative sources of energy could result in a change  
in the assumptions used to determine the recoverable amount and could affect estimating the future cash flows which could impact  
carrying amount of the Company’s intangible exploration assets. The timing of when global energy markets transition from carbon-  
based sources to alternative energy sources is highly uncertain. Environmental considerations are built into our estimates through  
the use of key assumptions in estimating fair value including future commodity prices and discount rates. The energy transition could  
impact the future prices of commodities and discount rates used to appraise oil and gas projects. Pricing assumptions used in the  
determination of recoverable amounts incorporate markets expectations and the evolving worldwide demand for energy.  
EQUITY METHOD  
Investments in joint ventures and investments in associates are accounted for using the equity method. Investments of this nature are  
recorded at original cost. Investments in joint ventures or associates which arise from a loss in control of a subsidiary are recorded at  
fair value on the date of the loss of control. The investment is adjusted periodically for the Company’s share of the profit or loss of the  
investment after the date of acquisition. The investor’s share of the profit or loss of the investee is also recognized in the Company’s  
Consolidated Statement of Net Income and Comprehensive Income. Distributions received reduce the carrying amount of the  
investment.  
Additionally, estimates associated with investments in joint ventures include the determination of amounts allocated to non-current  
assets as well as any negative goodwill associated with the acquisition.  
IMPAIRMENT OF JOINT VENTURES AND ASSOCIATES  
The amounts for investments in joint ventures and associates represent the Company’s equity interest in other entities, where there is  
either joint control or significant influence.The Company assesses investments in joint ventures and associates for impairment whenever  
changes in circumstances or events indicate that the carrying value may not be recoverable. The process of determining whether there  
is an indicator for impairment or calculating the recoverable amount requires judgement.  
The most material area in which the Company has applied judgement in the period is in relation to the investment in Prime. In assessing  
whether there are any indicators of impairment the Company has considered any effects of Prime’s forward sales arrangements, the  
loan facility, and any operational and contractual implications on the future dividend stream when assessing for impairment indicators.  
When any impairment indicators are identified, the entire carrying amount of the investment in the associate is compared to recoverable  
amount, which is the higher of value in use or fair value less costs of disposal. The Company has determined the recoverability of its  
investment will be in the form of dividends, and therefore has assessed the impact of current conditions on the recoverability of the  
dividends relative to the investment carrying value. The key assumptions the Company uses for estimating dividends include future  
commodity prices, operational scenarios provided by Prime, the timing of future cash flows and discount rates.  
CONTINGENT CONSIDERATION  
Contingent consideration formed part of the overall consideration for the acquisition of Prime. At the date of acquisition, an estimate  
of the contingent consideration is determined and included as part of the cost of the acquisition.  
Subsequent to acquisition, contingent consideration can be treated using two acceptable methods, the cost-based approach and  
the fair value-based approach. The Company have determined the cost-based approach to give the best estimate of the value of the  
contingent consideration. Any revisions to the contingent consideration estimates, after the date of acquisition, are accounted for as  
changes in estimates in accordance with IAS 8, to be accounted for on a prospective basis. The change in the liability, as a result of the  
revised cash flows, would be adjusted to the cost of the investment and, in accordance with paragraph 37 of IAS 8, recognized as part  
of the investment’s carrying amount rather than in profit or loss.  
The estimates involved in assessing the value of the contingent consideration include the expected timing of payments, the expected  
settlement value, the likelihood of settlement and the probability of the assessed outcomes occurring. There is significant judgement  
used in the determination of these estimates.  
PAGE 26  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
INTERNAL FINANCIAL REPORTING AND DISCLOSURE  
CONTROLS  
DISCLOSURE CONTROLS AND PROCEDURES  
Disclosure controls and procedures are designed to provide reasonable assurance that information required to be disclosed by the  
Company in its annual filings, interim filings or other reports filed or submitted by it under securities legislation is recorded, processed,  
summarized and reported within the time periods specified in the securities legislation and include controls and procedures designed  
to ensure that information required to be disclosed by the Company in its annual filings, interim filings or other reports filed or submitted  
under securities legislation is accumulated and communicated to the Company’s management, including its Chief Executive Officer  
and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure.  
Management, including the Chief Executive Officer and Chief Financial Officer, has evaluated the effectiveness of the design and  
operation of the Company’s disclosure controls and procedures. As of December 31, 2022, the Chief Executive Officer and Chief  
Financial Officer have each concluded that the Company’s disclosure controls and procedures, as defined in NI 52-109 - Certification of  
Disclosure in Issuer’s Annual and Interim Filings, are effective to achieve the purpose for which they have been designed.  
INTERNAL CONTROLS OVER FINANCIAL REPORTING  
Internal controls over financial reporting are designed to provide reasonable assurance regarding the reliability of financial reporting  
and the preparation of financial statements in accordance with IFRS. Management is also responsible for the design of the Company’s  
internal control over financial reporting in order to provide reasonable assurance regarding the reliability of financial reporting and the  
preparation of financial statements for external purposes in accordance with IFRS.  
The Company’s internal controls over financial reporting include policies and procedures that: pertain to the maintenance of records  
that, in reasonable detail accurately and fairly reflect the transactions and disposition of assets; provide reasonable assurance that  
transactions are recorded as necessary to permit preparation of the financial statements in accordance with IFRS and that receipts  
and expenditures are being made only in accordance with authorization of management and directors of the Company; and provide  
reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of assets that could have  
a material effect on the financial statements.  
Management, including the Chief Executive Officer and Chief Financial Officer, has evaluated the effectiveness of the design and  
operation of the Company’s internal controls over financial reporting. As at December 31, 2022, the Chief Executive Officer and Chief  
Financial Officer have each concluded that the Company’s internal controls over financial reporting,as defined in NI 52-109 - Certification  
of Disclosure in Issuer’s Annual and Interim Filings, are effective to achieve the purpose for which they have been designed. Because  
of their inherent limitations, internal controls over financial reporting can provide only reasonable assurance and may not prevent or  
detect misstatements. Furthermore, projections of any evaluation of effectiveness to future periods are subject to the risk that controls  
may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may  
deteriorate.  
ADVISORY REGARDING OIL AND GAS INFORMATION  
The terms boe (barrel of oil equivalent) and MMboe (millions of barrels of oil equivalent) are used throughout this report. Such  
terms may be misleading, particularly if used in isolation. The conversion ratio of six thousand cubic feet per barrel (6 Mcf:1 Bbl) of  
conventional natural gas to barrels of oil equivalent and the conversion ratio of 1 barrel per six thousand cubic feet (1 Bbl:6 Mcf) of  
barrels of oil to conventional natural gas equivalent is based on an energy equivalency conversion method primarily applicable at the  
burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude  
oil as compared to conventional natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1  
basis may be misleading as an indication of value.  
In this report, references are made to historical and potential future oil production in Nigeria and Kenya. In all instances these references  
are to light and medium crude oil category in accordance with NI 51-101 and the COGE Handbook.  
Reserves are estimated remaining quantities of petroleum anticipated to be recoverable from known accumulations, as of a given date,  
based on the analysis of drilling, geological, geophysical, and engineering data; the use of established technology; and specified  
economic conditions, which are generally accepted as being reasonable. Reserves are further classified according to the level of  
certainty associated with the estimates and may be sub-classified based on development and production status. Proved Reserves are  
those quantities of petroleum, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to  
be economically producible from a given date forward, from known reservoirs and under existing economic conditions, operating  
methods and government regulations. Probable Reserves are those additional quantities of petroleum that are less certain to be  
recovered than Proved Reserves, but which, together with Proved Reserves, are as likely as not to be recovered. Possible Reserves are  
those additional reserves that are less certain to be recovered than probable reserves. It is unlikely that actual remaining quantities  
recovered will exceed the sum of the estimated proved plus probable plus possible reserves.  
PAGE 27  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
RISK FACTORS  
With Board oversight, the Company proactively manages the identification, assessment and mitigation of risks, many of which are  
common to operations in the oil and gas industry as a whole, whilst others are unique to the Company. The realization of any of the risks  
listed below could have a material adverse effect on the Company’s business, financial condition, reserves and results of operations,  
such list being non-exhaustive.  
The risks noted in the risk factors section comprises those that can materially affect the figures presented and disclosures in the  
Financial Statements and MD&A. The Company’s Annual Information Form contains a more comprehensive list of risks that can affect  
the Company.  
Inflation Risk  
A failure to secure the services and equipment necessary for the Company’s operations for the expected price, on the expected  
timeline, or at all, may have an adverse effect on the Company’s financial performance and cash flows. The Company’s operating  
and capital costs could escalate and become uncompetitive due to supply chain disruptions, inflationary cost pressures, equipment  
limitations, escalating supply costs, commodity prices, and additional government intervention through stimulus spending or additional  
regulations.  
The Company’s inability to manage costs may impact project returns and future development decisions, which could have a material  
adverse effect on its financial performance and cash flows.In addition, with rising inflation levels combined with global cost of living  
expenses, the Company may be faced with the challenge of how to attract and retain employees.  
Prices, Markets and Marketing of Crude Oil and Natural Gas  
Oil and natural gas are commodities whose prices are determined based on world demand, supply and other factors, all of which are  
beyond the control of the Company. World prices for oil and natural gas have fluctuated widely in recent years. Any material decline  
in prices could have an adverse effect on the Company’s business and prospects. The Company may be required by Government  
authorities to limit production due to OPEC+ quotas from time to time.  
The conflict in Ukraine has impacted global markets and may continue to result in increased volatility in financial markets and commodity  
prices.  
The Company does not have a direct exposure to operations in Ukraine or Russia and does not have any business relationships with any  
sanctioned entities or people. The Company will continue to review all its engagements with new stakeholders to ensure this remains  
the case.  
The Company may undertake hedging activities when efficient to do so, however, they may not fully mitigate, in whole or in part, the  
risk and effect of lower oil prices.  
The Company or its investee company’s ability to market its oil and natural gas may depend upon its ability to acquire space on vessels  
or pipelines that deliver oil and natural gas to commercial markets. The Company could also be affected by deliverability uncertainties  
related to the proximity of its reserves to pipelines and processing and storage facilities and operational issues affecting such pipelines  
and facilities as well as government regulation relating to prices, taxes, royalties, land tenure, allowable production, the export of oil  
and natural gas and many other aspects of the oil and natural gas business.  
Liquidity and Cash Flow  
Liquidity risk is the risk that the Company will not be able to meet its financial obligations as they become due. Liquidity describes a  
company’s ability to access cash. Companies operating in the upstream oil and gas industry require sufficient cash in order to fulfill their  
work commitments in accordance with contractual obligations, and to be able to potentially acquire strategic oil and gas assets and  
face potentially unexpected liabilities.  
The Company will potentially issue debt or equity, extend its debt maturities and enter into farmout agreements to ensure it has  
sufficient available funds to meet current and foreseeable financial requirements. Concerns around climate change have resulted in  
some lenders and investors moving away from financing oil and gas activities, and the Company may find access to capital limited,  
more expensive or made contingent upon environmental performance standards.  
The Company periodically receives dividends from Prime related to the Company’s 50% shareholding in Prime, the amount and timing  
of which the Company does not control. However, a significant reduction, infrequent distributions, or no payment of Prime’s dividends  
to the Company could significantly reduce the amount of the Company’s anticipated cash flow and could also expose the Company to  
financial risk.  
The Company actively monitors its liquidity to ensure that its cash flows and working capital are adequate to support these financial  
obligations and the Company’s capital programs. The Company will also adjust the pace of its activities to manage its liquidity position.  
Notwithstanding any mitigation efforts, the Company remains exposed to erosion of its balance sheet and revenues and may have  
difficulty in securing necessary funding, which may lead to insufficient liquidity.  
PAGE 28  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
RISK FACTORS - CONTINUED  
Prime Dividends  
The Company occasionally receives dividends from Prime related to the Company’s 50% shareholding in Prime. However, a significant  
reduction, infrequent distributions, or no payment of Prime’s dividends to the Company could have a material or adverse effect on the  
Company’s business, and financial condition. Such results could occur due to, among other things, the following:  
Inability to achieve early licence renewal  
decline in the demand for oil and natural gas  
changes to the applicable tax and other laws and regulations in Nigeria  
Partner consensus  
an inability for Prime to hedge the production of future assets  
Prime’s off-takers defaulting on forward sale agreements or banks defaulting on hedging agreements  
significant or extended declines in oil and natural gas prices  
capital or liquidity constraints experienced by Prime, including restrictions imposed by lenders  
accounting delays or adjustments for prior periods  
shortages of, or delays in obtaining skilled personnel or equipment, including drilling rigs  
delays in the sale or delivery of products  
title defects  
global health emergencies  
A significant reduction or no payment of Prime’s dividends to the Company could significantly reduce the amount of the Company’s  
anticipated cash flow and could also expose the Company to financial risk.  
Credit Facilities  
The Company is party to credit facilities. The terms of the facility contain covenants and restrictions on the ability of the Company to,  
among other things, incur or lend additional debt, pay dividends and make restricted payments, and encumber its assets. The failure of  
the Company to comply with the covenants contained in the facility or to repay or refinance the facility by its maturity date could result  
in an event of default, which could, through acceleration of debt, enforcement of security or otherwise, materially and adversely affect  
the operating results and financial condition of the Company.  
Financial Statements Prepared on a Going Concern Basis  
The Company’s financial statements have been prepared on a going concern basis under which an entity is considered to be able  
to realize its assets and satisfy its liabilities in the ordinary course of business. The Company’s operations to date have been primarily  
financed by equity financing, dividends received from equity investments, debt financing and the completion of WI farmout agreements.  
The Company’s future operations may be dependent upon the identification and successful completion of additional equity or debt  
financing, the achievement of profitable operations (and profitable operations within equity investments) or other transactions. There  
can be no assurances that the Company will be successful in completing additional financings, achieving profitability or completing  
future transactions. The consolidated financial statements do not give effect to any adjustments relating to the carrying values and  
classification of assets and liabilities that would be necessary should the Company be unable to continue as a going concern.  
Substantial Capital Requirements  
The Company expects to make substantial capital expenditures for exploration, development and production of oil and gas reserves  
in the future. The Company’s ability to access the equity or debt markets may be affected by any prolonged market instability and  
changing requirements relating to climate change. The inability to access the equity or debt markets for sufficient capital, at acceptable  
terms and within required time frames, could have a material adverse effect on the Company’s financial condition, results of operations  
and prospects.  
To nance its future acquisition, exploration, development and operating costs, the Company may require financing from external  
sources, including from the issuance of new shares, issuance of debt or execution of WI farmout agreements. There can be no assurance  
that such financing will be available to the Company or, if available, that it will be offered on terms acceptable to the Company. If  
additional financing is raised through the issuance of equity or convertible debt securities, control of the Company may change and  
the interests of shareholders in the net assets of the Company may be diluted. If unable to secure financing on acceptable terms, the  
Company may have to cancel or postpone certain of its planned exploration and development activities which may ultimately lead to  
the Company’s inability to fulfill the minimum work obligations under the terms of its various concessions. Availability of capital will also  
directly impact the Company’s ability to take advantage of acquisition opportunities.  
Current Global Financial Conditions  
Global financial conditions have always been subject to volatility. These factors may impact the ability of the Company to obtain equity  
or debt financing in the future, and, if obtained, on terms favorable to the Company. Increased levels of volatility and market turmoil can  
adversely impact the Company’s operations and the value, and the price of the common shares could be adversely affected.  
PAGE 29  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
RISK FACTORS - CONTINUED  
Foreign Currency Exchange Rate Risk  
The Company is exposed to changes in foreign exchange rates as expenses in international subsidiaries, oil and gas expenditures, or  
financial instruments may fluctuate due to changes in rates. The Company’s exposure is partially offset by sourcing capital projects and  
expenditures in US dollars. The Company had no forward exchange contracts in place as at December 31, 2022.  
Credit Risk  
Credit risk is the risk of loss if counterparties do not fulfill their contractual obligations. Most of the Company’s credit exposure relates  
to amounts due from its joint venture partners. The risk of the Company’s joint venture partners defaulting on their obligations per their  
respective joint operating and farmout agreements is mitigated as there are contractual provisions allowing the Company to default  
joint venture partners who are non-performing and reacquire any previous farmed out WI. The maximum exposure for the Company  
is equal to the sum of its cash, restricted cash, and accounts receivable. A portion of the Company’s cash is held by banks in foreign  
jurisdictions where there could be increased exposure to credit risk.  
Limitation of Legal Remedies  
Securities legislation in certain of the provinces and territories of Canada provides purchasers with various rights and remedies when a  
reporting issuer’s continuous disclosure contains a misrepresentation and ongoing rights to bring actions for civil liability for secondary  
market disclosure. Under the legislation, the directors would be liable for a misrepresentation. It may be difficult for investors to collect  
from the directors who are resident outside Canada on judgements obtained in courts in Canada predicated on the purchaser’s  
statutory rights and on other civil liability provisions of Canadian securities legislation.  
Decommissioning  
The Company is responsible for compliance with all applicable laws, regulations and contractual requirements regarding the  
decommissioning, abandonment and reclamation of the Company’s assets at the end of their economic life, the costs of which  
may be substantial. It is not possible to predict these costs with certainty since they will be a function of requirements at the time of  
decommissioning, abandonment and reclamation and the actual costs may exceed current estimates. Laws, regulations and contractual  
requirements with regard to abandonment and decommissioning may be implemented or amended in the future.  
Risks Inherent in Oil and Gas Exploration, Development, and Production  
Oil and gas operations involve many risks, which, even with the combination of experience, knowledge, and careful evaluation may not  
be able to overcome. The long-term commercial success of Africa Oil depends on its ability to find, acquire, develop and commercially  
produce oil and natural gas reserves. No assurance can be given that the Company will be able to locate satisfactory properties for  
acquisition or participation. Moreover, if such acquisitions or participations are identified, the Company may determine that current  
markets, terms of acquisition and participation or pricing conditions make such acquisitions or participations uneconomic. It is difficult  
to project the costs of implementing an exploratory, appraisal or development drilling program due to the inherent uncertainties  
of drilling in unknown formations, the costs associated with encountering various drilling conditions such as over pressured zones,  
tools lost in the hole, and changes in drilling plans and locations as a result of prior exploratory wells or additional seismic data and  
interpretations thereof. Without the continual addition of new reserves, any existing reserves associated with the Company’s oil and gas  
assets at any particular time, and the production therefrom, could decline over time as such existing reserves are exploited. There is a  
risk that additional commercial quantities of oil and natural gas may not be discovered or acquired by the Company.  
Africa Oil’s business is subject to all the risks and hazards inherent in businesses involved in the exploration for, and the acquisition,  
development, production and marketing of, oil and natural gas, many of which cannot be overcome even with a combination of  
experience and knowledge and careful evaluation. The risks and hazards typically associated with oil and gas operations include fire,  
explosion, blowouts, sour gas releases, pipeline ruptures and oil spills, each of which could result in substantial damage to oil and  
natural gas wells, production facilities, other property, the environment or personal injury, and such damages may not be fully insurable.  
Reserves and Resources Volumes  
There are many uncertainties inherent in estimating quantities of oil and natural gas reserves and resources (contingent and prospective)  
and the future cash flows attributed to such reserves and resources. The actual production, revenues, taxes and development and  
operating expenditures with respect to the reserves and resources associated with the Company’s assets will vary from estimates  
thereof and such variations could be material. Estimates of reserves that may be developed and produced in the future are often based  
upon volumetric calculations and upon analogy to similar types of reserves rather than actual production history. There is uncertainty  
that it will be commercially viable to produce any portion of the contingent resources. Actual future net cash flows will be affected by  
other factors, such as actual production levels, supply and demand for oil and natural gas, curtailments or increases in consumption by  
oil and natural gas purchasers, changes in governmental regulation or taxation and the impact of inflation on costs.  
Government Regulations and Tax Risk  
The Company may be adversely affected by changes to applicable laws to which it is subject, and its host Governments may implement  
new applicable laws, modify existing ones, or interpret them in a manner that is detrimental to the Company. Such changes to the  
applicable law to which the Company is subject could, amongst other things, result in a windfall tax, an increase in existing tax rates or  
the imposition of new ones or the Company may be subject to tax assessments, all of which on their own or taken together could have  
a material adverse effect on the Company’s business, financial condition, results of operations and prospects of the Company’s oil and  
gas assets.  
As has become customary in Nigeria since 2019, the 2023 annual budget for Nigeria has been accompanied by a proposed Finance Act  
that supports the revenue needs that the budgets indicate. In line with that, in late December 2022, both chambers of Nigeria’s National  
Assembly passed the annual Finance Bill for 2023, which includes proposed changes to several different tax laws, including laws that  
can affect directly or indirectly the oil and gas industry. It is understood that the Finance Bill, which was passed on to the Presidential  
PAGE 30  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
RISK FACTORS - CONTINUED  
Office for its final ascension, has been returned to the National Assembly for further consultation and deliberation. Considering the  
recent Presidential and National Assembly elections and the transition to a new government, the timing for the final passage of the  
Finance Bill and its provisions, including changes that could be relevant to the oil and gas industry are uncertain. If there are adverse  
consequences to the oil and gas industry, this could cause further delay to the conversion of OML 127 and early renewal of OML 130.  
Nigeria’s general election took place on February 25, 2023 to elect the President and Vice President and members of the Senate and  
House of Representatives.  
Investments in Associates and Investments in Joint Ventures  
The Company has invested in other frontier oil and gas exploration companies that are similar to it, and that face similar risks and  
uncertainties, which could have a material adverse effect on their businesses, prospects and results of operations. Such risks include,  
without limitation, equity risk, liquidity risk, commodity price risk, credit risk, currency risk, foreign investment risk, and changes in  
environmental regulations, economic, political or market conditions, or the regulatory environment in the countries in which they  
operate. The associates or joint ventures are entities in which the Company has influence but given its equal interest or minority interest,  
no or limited control over their decisions, including, without limitation, financial and operational policies, and has no or limited control  
over financial outcomes and performances. The Company’s access to information is subject to the contractual provisions of Shareholder  
Agreements. The Company are reliant on the information provided by investments, and may not have the ability to independently  
verify such information. The Company’s investments are not diversified over different types of investments and industries, rather, they  
are concentrated in one type of investment. If an associated company or jointly controlled entity in which the Company has invested  
fails, liquidates, or becomes bankrupt, it could face the potential risk of loss of some, or all, of its investments, and the Company may  
be unable to recover its initial investment amount, or any amount, from its various investments in other frontier oil and gas exploration  
companies.  
International Operations  
The Company participates in oil and gas projects located in emerging markets, primarily in Africa. Oil and gas exploration, development  
and production activities in these emerging markets are subject to significant political, economic, and other uncertainties that may  
adversely affect the Company’s operations. The Company could be adversely affected by changes in applicable laws and policies  
in the countries where the Company has interests. Additional uncertainties include, but are not limited to, the risk of war, terrorism,  
expropriation, civil unrest, nationalization, renegotiation or nullification of existing or future concessions and contracts, the imposition  
of international sanctions, a change in crude oil or natural gas pricing policies, changes to taxation laws and policies, assessments  
and audits (including income tax) against the Company by regulatory authorities, difficulty or delays in obtaining necessary regulatory  
approvals, risks associated with potential future legal proceedings, and the imposition of currency controls. These uncertainties, all  
of which are beyond the Company’s control, could have a material adverse effect on the Company’s business, prospects and results  
of operations. In addition, if legal disputes arise related to oil and gas concessions acquired by the Company, they could be subject  
to the jurisdiction of courts other than those of Canada. The Company’s recourse may be very limited in the event of a breach by  
a government or government authority of an agreement governing a concession in which the Company acquires an interest. The  
Company may require licenses or permits from various governmental authorities to carry out future exploration, development and  
production activities. There can be no assurance that the Company will be able to obtain all necessary licenses and permits when  
required.  
Different Legal System and Litigation  
The Company’s exploration, development and production activities are located in countries with legal systems that in various degrees  
differ from that of Canada. Rules, regulations and legal principles may differ in respect of matters of substantive law and of such matters  
as court procedure and enforcement. Almost all material exploration and production rights and related contracts of the Company are  
subject to the national or local laws and jurisdiction of the respective countries in which the operations are carried out. This means that  
the Company’s ability to exercise or enforce its rights and obligations may differ between different countries and also from what would  
have been the case if such rights and obligations were subject to Canadian law and jurisdiction.  
The Company’s operations are, to a large extent, subject to various complex laws and regulations as well as detailed provisions in  
concessions, licenses and agreements that often involve several parties. If the Company was to become involved in legal disputes  
in order to defend or enforce any of its rights or obligations under such concessions, licenses, and agreements or otherwise, such  
disputes or related litigation could be costly, time consuming and the outcome would be highly uncertain. Even if the Company  
ultimately prevailed, such disputes and litigation may still have a substantially negative effect on the Company’s business, assets,  
financial conditions, and its operations.  
Anti-Bribery and Anti-Corruption Laws  
The Company is subject to various anti-bribery and anti-corruption laws, including the Corruption of Foreign Public Officials Act  
(Canada) and the Bribery Act 2010 (United Kingdom). Failure to comply with such laws could subject the Company to, among other  
things, reputational damage, civil and criminal penalties, other remedial measures and legal expenses which could adversely affect  
the Company’s business, results in operations, and financial condition. Weaknesses in the anti-corruption legal and judicial system of  
certain countries may undermine the Company’s or a host government’s capacity to effectively detect, prevent and sanction corruption.  
To mitigate this risk, the Company has implemented an anti-corruption compliance and onboarding program for anyone that does  
business with the Company, anti-corruption training initiatives for its personnel and consultants, and an anti-corruption policy for  
its personnel, and consultants. However, the Company cannot guarantee that its personnel, contractors, or business partners have  
not in the past or will not in the future engage in conduct undetected by the onboarding processes and procedures adopted by the  
Company, and it is possible that the Company, its personnel or contractors, could be subject to investigations or charges related to  
bribery or corruption as a result of actions of its personnel or contractors.  
PAGE 31  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
RISK FACTORS - CONTINUED  
Shared Ownership and Dependency on Partners  
The Company’s operations are primarily conducted together with one or more joint venture partners through contractual arrangements,  
including unincorporated associations. In such instances, the Company may be dependent on, or affected by, the due performance and  
financial strength of its partners. If a partner fails to perform or becomes insolvent, the Company may, among other things, risk losing  
rights or revenues or incur additional obligations or costs, experience delays, or be required to perform such obligations in place of its  
partners. The Company and its partners may also, from time to time, have different opinions on how to conduct certain operations or on  
what their respective rights and obligations are under a certain agreement. If a dispute were to arise with one or more partners relating  
to a project, such dispute may have material adverse effect on the Company’s or investee company’s operations relating to such project.  
Risks Relating to Concessions, Licenses and Contracts  
The Company’s operations are based on a relatively limited number of concession agreements, licenses and contracts. The rights and  
obligations under such concessions, licenses and contracts may be subject to interpretation and could also be affected by, among  
other things, matters outside the control of the Company. In case of a dispute, it cannot be certain that the view of the Company would  
prevail or that the Company otherwise could effectively enforce its rights which, in turn, could have significantly negative effects on it.  
Also, if the Company or any of its partners were found to have failed to comply with their obligations or liabilities under a concession,  
license or contract, including record-keeping, budgeting, and time scheduling requirements under production sharing contracts, the  
Company’s or partner’s rights under such concession, license or contract may be terminated or otherwise relinquished in whole or  
in part. The Company cannot guarantee that requirements are adequately met by its joint venture partners, which could bring an  
increased risk of impairment and reduced future cash flow.  
Risks Relating to Audits and Cost-Recovery Oil (Kenya)  
Under the terms of the Company’s Block 10BA, Block 10BB, and Block 13T production sharing contracts, up to a stated maximum  
percentage of net available oil is available for cost-recovery by the respective joint venture partners. Costs subject to cost recovery  
includeallcostsandexpendituresincurredbythejointventurepartnersforexploration,development,production,anddecommissioning  
operations, as well as any other applicable costs and expenditures incurred directly or indirectly with such activities. Such costs may  
be subject to audits which could identify amounts claimed by the joint venture partners as being disallowed expenditures, which  
could negatively impact the joint ventures’ ability to recover and develop projects, as planned. Such costs may also form the basis  
of consideration in historical and future farm out agreements. The Company cannot guarantee that record-keeping, accounting,  
budgeting, and time scheduling requirements are adequately met by its joint venture partners, which could bring an increased risk of  
impairment, claims between joint venture partners, and reduced future cash flow.  
CLIMATE RISKS  
Market Risks  
Changing consumer preferences for low carbon sources of energy, transport and products and services may erode demand for oil and  
gas as clean alternatives come to market and gain scale. Reduced demand for oil and gas may result in stranded reserves or resources  
and negatively impact the Company’s valuation and share price. In addition to limiting the Company’s ability to sell into the market,  
these trends could lead to lower commodity prices in the medium and long-term, putting further pressure on revenues. In the short-  
term, unbalanced investment in traditional vs. new energy technologies and sources, combined with uncertain demand dynamics, may  
lead to commodity price volatility. Supply chains may also become constrained, as suppliers adjust their strategies and product mix in  
response to the energy transition, resulting in increasing costs for some goods and services.  
The Company has conducted scenario analysis, which suggests the current portfolio remains competitive in a low demand environment.  
We will update the analysis on a regular basis and ahead of new project sanction to minimise the risk of stranded assets. In order to  
remain resilient in an uncertain and volatile future commodity environment, the Company will work with and through its partners to  
reduce operational costs as much as possible without sacrificing health and safety or longer-term efficiency and environmental goals.  
Though Africa Oil does not directly control procurement decisions associated with our assets, the Company will work with our partners  
to ensure adequate contingency for cost inflation is incorporated into capital and operating budgets and that costs are controlled  
within budget. Additionally, the Company will maintain a prudent budget and financial strategy, including hedging as appropriate, to  
manage oil price volatility ensure the business remains resilient in a low oil price environment.  
At the same time, markets for new products and services may present opportunities for the Company to expand or diversify the  
Company’s lines of business, helping to grow or at least offset potential losses of revenue associated with our traditional business  
activities as demand for oil and gas declines or even grow revenue. For instance, we are exploring development of an offset project in  
Kenya of sufficient scale to help mitigate both our own emissions as well as potentially third-party emissions.  
Litigation Risks  
Climate-related litigation is a rapidly evolving and increasingly important issue for our industry. The risk of legal challenges could rise  
as the costs of climate change mitigation and adaptation increase, and as more climate laws and agreements are put in place. Climate-  
related litigation could result in liabilities or loss of license related to current or historical activities’ contribution to global emissions.  
We do not consider Africa Oil at immediate risk of climate litigation but are monitoring developments closely. Even if the Company  
is not directly targeted by litigation, operations may be indirectly impacted by outcomes in related cases involving other oil and gas  
companies in jurisdictions where we operate. The Company will seek legal counsel as required to remain abreast of potential legal  
action and its implications for our business.  
PAGE 32  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
FORWARD-LOOKING STATEMENTS - CONTINUED  
Regulatory Risks  
Since the Paris Agreement was signed in 2015, countries have steadily enacted policies to enable the transition to a low carbon future  
and meet their Nationally Determined Contributions (NDCs). This includes the governments of countries where Africa Oil conducts  
business. These policies may directly or indirectly increase the cost of doing business in these countries or potentially restrict our  
ability to operate. Africa Oil regularly monitors the evolving regulatory landscape, both globally and in our countries of operation,  
to anticipate the impact of new climate-related measures and ensure we remain compliant. Additionally, the Company is developing  
a comprehensive energy transition strategy, including measures to minimise operational emissions in line with Paris Agreement  
objectives, which should help to remain aligned with evolving regulatory requirements and minimise negative impacts.  
Reputational Risk  
Increased scrutiny, pressure and action by environmental activists, non-governmental organisations and other stakeholders may result  
in disruption to operations or loss of license to operate. Such disruption may negatively impact cash flows, returns or the value of our  
portfolio. Similarly, companies within the sector and our supply chain may make emissions performance and climate risk management  
explicit in partner or contract decisions, The Company has not been directly targeted by environmental activists but could be targeted  
in the future. To mitigate this risk, Africa Oil proactively engages with the communities and other stakeholders where the Company  
operates to keep them informed about the impact of our operations on the environment and their livelihoods. The Company also  
ensures proper security is in place to minimise the impact of any potential disruptions and prevent harm to staff, bystanders and assets.  
In addition to environmental activists, numerous banks and large institutional investors have communicated an intention to divest from  
or limit future exposure to fossil fuels, including oil and gas. Increasing investor and lender concerns regarding climate resilience could  
limit access to capital, increase the cost of that capital via higher interest rates or result in direct costs associated with new measures  
to meet investor expectations. Since 2020, Africa Oil has published public climate disclosures aligned with the Taskforce for Climate-  
Related Financial Disclosures (TCFD) recommendations to proactively address investor and other stakeholder concerns regarding  
climate risk exposure. In addition, Africa Oil regularly engages with investors and lenders to understand their climate policies and  
requirements and to inform them about the steps the Company is taking to manage climate risks. This includes development of a  
comprehensive energy transition strategy to minimise operational emissions.  
Technology Risks  
Evolution and proliferation of clean energy technologies, including renewables, electric vehicles, hydrogen and other clean fuels, and  
energy management technologies such as the Internet of Things, may reduce oil and gas’s share of the energy market in the medium  
and long term, making our business model unsustainable. The Company will work with and through our partners to reduce operational  
costs as much as possible without sacrificing health and safety or longer-term efficiency and environmental goals to ensure they remain  
resilient in a low demand, low oil price environment. Additionally, we may explore diversifying into alternative, lower carbon business  
lines as part of a comprehensive energy transition strategy.  
In addition to new business lines, the evolution of clean energy technologies present opportunities for integration with our operations  
to lower our own emissions footprint. Specifically, the Field Development Plan for our Kenyan assets includes use of solar power to  
support administrative loads, and we have explored broader use of renewables to power operations at the facility.  
Physical Risks  
Climate change has already resulted in significant shifts in global weather patterns, including an increase in the number and severity  
of heat waves, cold spells, droughts and storms, including hurricanes and tropical cyclones. Longer term, climate change may also  
result in rising sea levels due to melting polar ice caps. The physical effects of climate change have the potential to directly impact the  
Company’s assets and operations. In 2022, the Company contracted a global climate risk analytics company to perform a quantified  
assessment of the physical climate risks facing the Company’s assets under three IPCC climate scenarios: SSP1-2.6 (consistent with 1.8°C  
warming), SSP2-4.5 (consistent with 2.7°C warming) and SSP5-8.5 (consistent with 4.4°C warming). That analysis suggests exposure  
to future changes in physical climate hazards is relatively minimal compared to the historical baseline across all three scenarios and  
limited to increasing precipitation and risk of drought in Kenya. We will continue to monitor our assets’ exposure to physical climate  
risks as our portfolio and the global scientific community’s understanding of changing climate patterns evolves.  
FORWARD-LOOKING STATEMENTS  
Certain statements in this document may constitute forward-looking information or forward-looking statements under applicable  
Canadian securities law (collectively “forward-looking statements”). Forward-looking statements are statements that relate to future  
events, including the Company’s future performance, opportunities or business prospects. Any statements that express or involve  
discussions with respect to expectations, forecasts, assumptions, objectives, beliefs, projections, plans, guidance, predictions, future  
events or performance (often, but not always, identified by words such as “believes, seeks, “anticipates, “expects, “continues,  
“may, projects, “estimates, forecasts, pending, intends, plans, “could, might, should, will, would have” or similar words  
suggesting future outcomes) are not statements of historical fact and may be forward-looking statements.  
By their nature, forward-looking statements involve assumptions, inherent risks and uncertainties, many of which are difficult to predict,  
and are usually beyond the control of management, that could cause actual results to be materially different from those expressed by  
these forward-looking statements. Undue reliance should not be placed on these forward-looking statements because the Company  
cannot assure that the forward-looking statements will prove to be correct. As forward-looking information address future conditions  
and events, they could involve risks and uncertainties including, but are not limited to, risk with respect to general economic conditions,  
regulations and taxes, civil unrest, corporate restructuring and related costs, capital and operating expenses, pricing and availability  
of financing and currency exchange rate fluctuations. Readers are cautioned that the assumptions used in the preparation of such  
information, although considered reasonable at the time of preparation, may prove to be imprecise and, as such, undue reliance should  
not be placed on forward-looking statements.  
PAGE 33  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
FORWARD-LOOKING STATEMENTS - CONTINUED  
COVID-19 has had a significant impact on the oil and gas industry, including a substantial reduction in oil demand worldwide, market  
volatility and oil price weakness. There has been a robust response by international oil producers led by the group of OPEC+ countries  
to reduce supply and address the challenge of demand destruction. The group have started to relax the quotas they have imposed but  
the Company cannot assure that the oil producers’ response can remove significant supply to address the demand destruction, flatten  
the curve of inventory builds and set a course to rebalance markets, nor can the Company predict the time it will take for oil demand to  
recover to the pre-pandemic level. Such adverse effects may continue and could affect the Company and the Company’s share price.  
Forward-looking statements include, but are not limited to, statements concerning:  
A change to the shareholder capital return program including the implementation of share buy-backs;  
The Company’s plans to prepare an Energy Transition Plan and the steps to be taken by the Company in relation to the Energy  
Transition Plan;  
Expected closing dates for the completion of proposed transactions;  
Planned exploration, appraisal and development activity including both expected drilling and target drilling dates, and geological  
and geophysical related activities;  
Potential for an improved economic environment;  
The Company’s anticipated timing for the receipt of dividends from Prime;  
The Company’s plans to prioritize repayment of its long-term debt, utilizing dividends received from Prime;  
Proposed development plans;  
Future development costs and the funding thereof;  
Expected finding and development costs;  
Anticipated future financing requirements;  
Future sources of funding for the Company’s capital program;  
Future capital expenditures and their allocation to exploration and development activities;  
Ability for the Company to remain within existing financial headroom;  
Expected operating costs;  
Future sources of liquidity, ability to fully fund the Company’s expenditures from cash flows, and borrowing capacity;  
Availability of potential farmout partners;  
Government or other regulatory consent for exploration, development, farmout, or acquisition activities;  
Future production levels;  
Future crude oil, natural gas or chemical prices;  
Future earnings;  
Future asset acquisitions or dispositions;  
Future debt levels;  
Availability of committed credit facilities, including existing credit facilities, on terms and timing acceptable to the Company;  
Possible commerciality;  
Development plans or capacity expansions;  
Future ability to execute dispositions of assets or businesses;  
Future drilling of new wells;  
Ultimate recoverability of current and long-term assets;  
Ultimate recoverability of reserves or resources;  
Estimates on a per share basis;  
Future foreign currency exchange rates;  
Future market interest rates;  
Future expenditures and future allowances relating to environmental matters;  
Dates by which certain areas will be explored or developed or will come on stream or reach expected operating capacity;  
The Company’s ability to comply with future legislation or regulations;  
Future staffing level requirements; and  
Changes in any of the foregoing.  
Statements relating to “reserves” or “resources” are forward-looking statements, as they involve the implied assessment, based on  
estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated, and can be  
profitably produced in the future.  
These forward-looking statements are subject to known and unknown risks and uncertainties and other factors, which may cause actual  
results, levels of activity and achievements to differ materially from those expressed or implied by such statements. Such factors include,  
among others:  
PAGE 34  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
FORWARD-LOOKING STATEMENTS - CONTINUED  
Market prices for oil and gas and chemical products;  
Uncertainty of estimates and projections relating to reserves, resources, production, revenues, costs and expenses;  
Changes in exploration or development project plans or capital expenditures;  
The Company’s ability to explore, develop, produce and transport crude oil and natural gas to markets;  
Production and development costs and capital expenditures;  
The imprecise nature of reserve estimates and estimates of recoverable quantities of oil, natural gas and liquids;  
Changes in oil prices;  
Availability of financing;  
Uninsured risks;  
Changes in interest rates and exchange rates;  
Regulatory changes;  
Changes in the social climate in the regions in which the Company operates;  
Health, safety and environmental risks;  
Climate change legislation and regulation changes;  
Defects in title;  
Availability of materials and equipment;  
Timelines of government or other regulatory approvals;  
Ultimate effectiveness of design or design modification to facilities;  
The results of exploration, appraisal and development drilling and related activities;  
Short-term well test results on exploration and appraisal wells do not necessarily indicate the long-term performance or ultimate  
recovery that may be expected from a well;  
Pipeline or delivery constraints;  
Volatility in energy trading markets;  
Incorrect assessments of value when making acquisitions;  
Foreign-currency exchange rates;  
Economic conditions in the countries and regions in which the Company carries on business;  
Governmental actions including changes to taxes or royalties, and changes in environmental and other laws and regulations;  
The Company’s treatment under governmental regulatory regimes and tax laws;  
Renegotiations of contracts;  
Results of litigation, arbitration or regulatory proceedings;  
Political uncertainty, including actions by terrorists, insurgent or other groups, or other armed conflict; and  
Internal conflicts within states or regions.  
The impact of any one risk, uncertainty or factor on a particular forward-looking statement is not determinable with certainty as these  
factors are interdependent, and management’s future course of action would depend on its assessment of all available information at  
that time. Although management believes that the expectations conveyed by the forward-looking statements are reasonable based  
on the information available to it on the date such forward-looking statements were made, no assurances can be given that such  
expectations will prove to be correct, and such forward-looking statements included in this document should not be unduly relied  
upon.  
The forward-looking statements are made as of the date hereof or as of the date specified in this document, as the case may be, and  
except as required by law, the Company undertakes no obligation to update publicly, re-issue, or revise any forward-looking statements,  
whether as a result of new information, future events or otherwise. This cautionary statement expressly qualifies the forward-looking  
statements contained herein.  
PAGE 35  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
Independent auditor’s report  
To the Shareholders of Africa Oil Corp.  
Our opinion  
In our opinion, the accompanying consolidated financial statements present fairly, in all material respects,  
the financial position of Africa Oil Corp. and its subsidiaries (together, the Company) as at December 31,  
2022 and 2021 and January 1, 2021, and its financial performance and its cash flows for the years ended  
December 31, 2022 and 2021 in accordance with International Financial Reporting Standards as issued  
by the International Accounting Standards Board (IFRS).  
What we have audited  
The Company’s consolidated financial statements comprise:  
the consolidated balance sheets as at December 31, 2022 and 2021 and January 1, 2021;  
the consolidated statements of net (loss)/ income and comprehensive (loss)/ income for the years  
ended December 31, 2022 and 2021;  
the consolidated statements of equity for the years ended December 31, 2022 and 2021;  
the consolidated statements of cash flows for the years ended December 31, 2022 and 2021; and  
the notes to the consolidated financial statements, which include significant accounting policies and  
other explanatory information.  
Basis for opinion  
We conducted our audit in accordance with Canadian generally accepted auditing standards. Our  
responsibilities under those standards are further described in the Auditor’s responsibilities for the audit of  
the consolidated financial statements section of our report.  
We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for  
our opinion.  
Independence  
We are independent of the Company in accordance with the ethical requirements that are relevant to our  
audit of the consolidated financial statements in Canada. We have fulfilled our other ethical responsibilities  
in accordance with these requirements.  
PricewaterhouseCoopers LLP  
111-5th Avenue SW, Suite 3100, Calgary, Alberta, Canada T2P 5L3  
T: +1 403 509 7500, F: +1 403 781 1825  
“PwC” refers to PricewaterhouseCoopers LLP, an Ontario limited liability partnership.  
PAGE 36  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
Key audit matters  
Key audit matters are those matters that, in our professional judgment, were of most significance in our  
audit of the consolidated financial statements for the year ended December 31, 2022. These matters were  
addressed in the context of our audit of the consolidated financial statements as a whole, and in forming  
our opinion thereon, and we do not provide a separate opinion on these matters.  
Key audit matter  
How our audit addressed the key audit matter  
Impairment assessment of intangible  
exploration assets of the Project Oil Kenya  
cash generating unit  
Our approach to addressing the matter included the  
following procedures, among others:  
Tested how management determined the  
recoverable amount of the Project Oil  
Kenya CGU, which included the following:  
Refer to note 2 – Basis of preparation, note 3 –  
Significant accounting policies and note 7 –  
Intangible exploration assets to the consolidated  
financial statements.  
o
o
Evaluated the appropriateness of  
the method used by management.  
As at December 31, 2022, the carrying amount of  
the Company’s intangible exploration assets was  
$63.6 million, which includes $58.5 million related  
to the Project Oil Kenya cash generating unit (Block  
10BB and 13T) (Project Oil Kenya CGU). The  
carrying amounts of the Company’s intangible  
exploration assets are reviewed at each reporting  
date to determine whether there is any indication of  
impairment. Intangible exploration assets are  
assessed for impairment if facts and circumstances  
suggest that the carrying amount exceeds the  
recoverable amount. If any such indication exists,  
then the intangible exploration asset’s recoverable  
amount is estimated. For the purpose of  
impairment testing, intangible exploration assets  
are grouped together into a cash generating unit  
(CGU). The recoverable amount of a CGU is the  
higher of fair value less costs to dispose and its  
value in use. Should the carrying amount of the  
CGU exceed the recoverable amount, an  
Tested the underlying data used in  
determining the recoverable  
amount.  
o
Evaluated the reasonableness of  
significant assumptions used by  
management in developing the  
recoverable amount, including:  
operating expenses and  
development costs by  
considering the past  
performance of the Project  
Oil Kenya CGU and  
whether these  
assumptions were  
consistent with evidence  
obtained in other areas of  
the audit; and  
impairment loss is recognized.  
future commodity prices by  
comparing those forecasts  
with third party industry  
forecasts.  
As at December 31, 2022, management  
determined that there was an indicator of  
impairment for the Project Oil Kenya CGU. The  
Company and its JV partners are actively seeking  
strategic partners for the project and it is intended  
PAGE 37  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
Key audit matter  
How our audit addressed the key audit matter  
that a strategic partner will be secured ahead of a  
financial investment decision (FID). As there have  
been continuing delays and uncertainties to the  
farm out process, management considered this an  
indicator for impairment. As a result of the  
impairment indicator, management performed an  
impairment test. Management used fair value less  
costs of disposal using a discounted cash flow  
method (level 3) to determine the recoverable  
amount of the Project Oil Kenya CGU.  
The work of management’s experts was  
used in performing the procedures to  
evaluate the reasonableness of the  
estimates for the quantity of contingent  
resources and production forecasts. As a  
basis for using this work, the competence,  
capabilities and objectivity of  
management’s experts was evaluated, the  
work performed was understood and the  
appropriateness of the work as audit  
evidence was evaluated. The procedures  
performed also included evaluation of the  
methods and assumptions used by  
management’s experts, tests of the data  
used by management’s experts and an  
evaluation of their findings.  
Significant assumptions developed by management  
used to determine the recoverable amount of the  
Project Oil Kenya CGU included estimates for the  
quantity of contingent resources, future commodity  
prices, production forecasts, operating expenses,  
development costs, the likelihood of a successful  
farm out process, the timing of FID and the  
discount rate. The estimates for the quantity of  
contingent resources and production forecasts are  
prepared by the Company’s independent petroleum  
engineers (management’s experts).  
Professionals with specialized skill and  
knowledge in the field of valuation assisted  
with developing an independent point  
estimate for the discount rate, which  
considered the likelihood of a successful  
farm out process and the timing of FID; and  
compared the independent point estimate  
to management’s estimate to evaluate the  
reasonableness of management’s discount  
rate.  
The results of the impairment test indicated that the  
carrying value of the Project Oil Kenya CGU  
exceeded its recoverable amount and the  
Company recognized an impairment loss of $170.6  
million.  
We considered this a key audit matter due to (i) the  
significant judgment by management, including the  
use of management’s experts, when determining  
the recoverable amount of the Project Oil Kenya  
CGU (ii) a high degree of auditor judgment,  
subjectivity and effort in performing procedures  
relating to management’s significant assumptions  
and (iii) the audit effort that involved the use of  
professionals with specialized skill and knowledge  
in the field of valuation.  
PAGE 38  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
Key audit matter  
How our audit addressed the key audit matter  
Impairment assessment of equity accounted  
investment in Prime  
Our approach to addressing the matter included the  
following procedures, among others:  
Refer to note 2 – Basis of preparation, note 3 –  
Significant accounting policies and note 5 – Equity  
investment in joint venture to the consolidated  
financial statements.  
Tested how management determined the  
recoverable amount of the equity  
accounted investment in Prime, which  
included the following:  
The carrying amount of the Company’s equity  
accounted investment in Prime Oil and Gas  
Coöperatief U.A. (Prime) was $513.7 million as at  
December 31, 2022.  
Evaluated the appropriateness of  
the method used by management.  
Tested the underlying data used in  
determining the recoverable  
amount.  
Management assesses the equity accounted  
investment in Prime for impairment whenever  
changes in circumstances or events indicate that  
the carrying value may not be recoverable. If such  
impairment indicators exist, the carrying amount of  
the equity accounted investment in Prime is  
compared to its recoverable amount. The  
Evaluated the reasonableness of  
significant assumptions used in  
developing the underlying  
estimates, including:  
recoverable amount is the higher of the equity  
accounted investment in Prime’s fair value less  
costs to dispose and its value in use. The equity  
accounted investment in Prime is written down to  
its recoverable amount when its carrying amount  
exceeds the recoverable amount.  
operating and capital costs  
by considering the past  
performance of Prime and  
whether these  
assumptions were  
consistent with evidence  
obtained in other areas of  
the audit.  
As at December 31, 2022, management  
determined that there was an indicator of  
impairment in relation to the Company’s equity  
accounted investment in Prime arising from an  
impairment recognized by Prime. As a result, an  
impairment test was performed. Management  
determined the recoverable amount of the equity  
accounted investment in Prime by calculating the  
value in use derived from the discounted cash flow  
forecast of the dividend stream to be received from  
Prime. Significant assumptions developed by  
management to support the forecasted dividend  
stream used to determine the recoverable amount  
of the equity accounted investment in Prime  
included; estimates for the quantity of proved and  
probable petroleum reserves, future commodity  
prices, operating and capital costs as well as  
future commodity prices by  
comparing those forecasts  
with third party industry  
forecasts; and  
the discount rates, through  
the assistance of  
professionals with  
specialized skill and  
knowledge in the field of  
valuation.  
PAGE 39  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
Key audit matter  
How our audit addressed the key audit matter  
The work of management’s experts was  
discount rates. The quantity of proved and probable  
petroleum reserves are prepared by Prime’s  
independent petroleum engineers (management’s  
experts).  
used in performing the procedures to  
evaluate the reasonableness of the  
estimates for the quantity of proved and  
probable petroleum reserves. As a basis  
for using this work, the competence,  
capabilities and objectivity of  
management’s experts was evaluated, the  
work performed was understood and the  
appropriateness of the work as audit  
evidence was evaluated. The procedures  
performed also included evaluation of the  
methods and assumptions used by  
management’s experts, tests of the data  
used by management’s experts and an  
evaluation of their findings.  
The results of the impairment test indicated that the  
recoverable amount of the equity accounted  
investment in Prime was in excess of the carrying  
value.  
We considered this is a key audit matter due to (i)  
the significant judgment made by management,  
including the use of management’s experts, when  
determining the recoverable amount of the equity  
accounted investment in Prime (ii) a high degree of  
auditor judgment, subjectivity and effort in  
performing procedures relating to the significant  
assumptions and (iii) the audit effort that involved  
the use of professionals with specialized skill and  
knowledge in the field of valuation.  
Other information  
Management is responsible for the other information. The other information comprises the Management’s  
Discussion and Analysis.  
Our opinion on the consolidated financial statements does not cover the other information and we do not  
express any form of assurance conclusion thereon.  
In connection with our audit of the consolidated financial statements, our responsibility is to read the other  
information identified above and, in doing so, consider whether the other information is materially  
inconsistent with the consolidated financial statements or our knowledge obtained in the audit, or  
otherwise appears to be materially misstated.  
If, based on the work we have performed, we conclude that there is a material misstatement of this other  
information, we are required to report that fact. We have nothing to report in this regard.  
Responsibilities of management and those charged with governance for the  
consolidated financial statements  
Management is responsible for the preparation and fair presentation of the consolidated financial  
statements in accordance with IFRS, and for such internal control as management determines is  
PAGE 40  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
necessary to enable the preparation of consolidated financial statements that are free from material  
misstatement, whether due to fraud or error.  
In preparing the consolidated financial statements, management is responsible for assessing the  
Company’s ability to continue as a going concern, disclosing, as applicable, matters related to going  
concern and using the going concern basis of accounting unless management either intends to liquidate  
the Company or to cease operations, or has no realistic alternative but to do so.  
Those charged with governance are responsible for overseeing the Company’s financial reporting  
process.  
Auditor’s responsibilities for the audit of the consolidated financial statements  
Our objectives are to obtain reasonable assurance about whether the consolidated financial statements as  
a whole are free from material misstatement, whether due to fraud or error, and to issue an auditor’s  
report that includes our opinion. Reasonable assurance is a high level of assurance, but is not a  
guarantee that an audit conducted in accordance with Canadian generally accepted auditing standards  
will always detect a material misstatement when it exists. Misstatements can arise from fraud or error and  
are considered material if, individually or in the aggregate, they could reasonably be expected to influence  
the economic decisions of users taken on the basis of these consolidated financial statements.  
As part of an audit in accordance with Canadian generally accepted auditing standards, we exercise  
professional judgment and maintain professional skepticism throughout the audit. We also:  
Identify and assess the risks of material misstatement of the consolidated financial statements,  
whether due to fraud or error, design and perform audit procedures responsive to those risks, and  
obtain audit evidence that is sufficient and appropriate to provide a basis for our opinion. The risk of  
not detecting a material misstatement resulting from fraud is higher than for one resulting from  
error, as fraud may involve collusion, forgery, intentional omissions, misrepresentations, or the  
override of internal control.  
Obtain an understanding of internal control relevant to the audit in order to design audit procedures  
that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the  
effectiveness of the Company’s internal control.  
Evaluate the appropriateness of accounting policies used and the reasonableness of accounting  
estimates and related disclosures made by management.  
Conclude on the appropriateness of management’s use of the going concern basis of accounting  
and, based on the audit evidence obtained, whether a material uncertainty exists related to events  
or conditions that may cast significant doubt on the Company’s ability to continue as a going  
concern. If we conclude that a material uncertainty exists, we are required to draw attention in our  
auditor’s report to the related disclosures in the consolidated financial statements or, if such  
disclosures are inadequate, to modify our opinion. Our conclusions are based on the audit evidence  
obtained up to the date of our auditor’s report. However, future events or conditions may cause the  
Company to cease to continue as a going concern.  
PAGE 41  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
Evaluate the overall presentation, structure and content of the consolidated financial statements,  
including the disclosures, and whether the consolidated financial statements represent the  
underlying transactions and events in a manner that achieves fair presentation.  
Obtain sufficient appropriate audit evidence regarding the financial information of the entities or  
business activities within the Company to express an opinion on the consolidated financial  
statements. We are responsible for the direction, supervision and performance of the group audit.  
We remain solely responsible for our audit opinion.  
We communicate with those charged with governance regarding, among other matters, the planned scope  
and timing of the audit and significant audit findings, including any significant deficiencies in internal  
control that we identify during our audit.  
We also provide those charged with governance with a statement that we have complied with relevant  
ethical requirements regarding independence, and to communicate with them all relationships and other  
matters that may reasonably be thought to bear on our independence, and where applicable, related  
safeguards.  
From the matters communicated with those charged with governance, we determine those matters that  
were of most significance in the audit of the consolidated financial statements of the current period and  
are therefore the key audit matters. We describe these matters in our auditor’s report unless law or  
regulation precludes public disclosure about the matter or when, in extremely rare circumstances, we  
determine that a matter should not be communicated in our report because the adverse consequences of  
doing so would reasonably be expected to outweigh the public interest benefits of such communication.  
The engagement partner on the audit resulting in this independent auditor’s report is Khurram Asghar.  
Chartered Professional Accountants  
Calgary, Alberta  
February 27, 2023  
PAGE 42  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
CONSOLIDATED  
BALANCE SHEETS  
(Expressed in millions of United States dollars)  
December 31,  
2022  
December 31,  
2021  
January 1,  
2021  
As at  
Note  
See note 2c  
ASSETS  
Current assets  
Cash and cash equivalents  
Accounts receivable and prepaid expenses  
4
199.7
1.4
58.9
0.6
40.5
1.4
201.1
59.5
41.9
Long-term assets  
Equity investment in joint venture  
Equity investments in associates  
Intangible exploration assets  
Property and equipment  
5
6
513.7
137.3
63.6
-
617.1
120.7
194.3
-
561.3
116.2
190.6
0.5
7
-
Loan to associated company  
17  
2.0
-
-
716.6
932.1
868.6
Total assets  
917.7
991.6
910.5
LIABILITIES AND EQUITY  
Current liabilities  
Accounts payable and liabilities  
Share-based compensation liability  
8
37.2
7.3
3.7
4.0
7.7
11.2
1.6
15  
44.5
12.8
Long-term liabilities  
Share-based compensation liability  
Provision for contingent consideration  
Provision for site restoration  
Long-term debt  
15  
5
5.3
32.0
5.3
-
3.9
32.0
-
2.4
-
-
9
10  
-
141.0
143.4
42.6
35.9
Total liabilities  
87.1
43.6
156.2
Equity attributable to common shareholders  
Share capital  
11(B)  
1,267.7
59.2
1,309.1
51.1
1,306.5
50.8
Contributed surplus  
Deficit  
(496.3)
-
(412.2)
-
(610.7)
7.7
Accumulated other comprehensive income  
Total equity attributable to common shareholders  
830.6
948.0
754.3
Total liabilities and equity attributable to common shareholders  
917.7
991.6
910.5
The notes are an integral part of the consolidated financial statements.  
Approved on behalf of the Board:  
“ANDREW BARTLETT”  
“KEITH HILL”  
ANDREW BARTLETT, DIRECTOR  
KEITH HILL, DIRECTOR  
PAGE 43  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
CONSOLIDATED STATEMENTS OF NET (LOSS)/  
INCOME AND COMPREHENSIVE (LOSS)/ INCOME  
(Expressed in millions of United States dollars)  
December 31,  
2022  
December 31,  
For the years ended  
Note  
2021  
Operating income  
Share of profit from investment in joint venture  
Share of (loss)/ income from investments in associates  
5
6
146.6
(8.2)
224.4
2.5
Total operating income  
138.4
226.9
Operating expenses  
Salaries and benefits  
(6.2)
(9.5)
(6.3)
(6.3)
(5.4)
-
Share-based compensation  
15  
7
Professional fees and other general and administrative expenses  
Impairment of intangible exploration assets  
Total operating expense  
(11.3)
(170.6)
(197.6)
(18.0)
Net operating (loss)/ income  
(59.2)
208.9
Finance income  
13  
13  
2.4
(3.5)
0.1
(18.3)
190.7
Finance expense  
Net (loss)/ income attributable to common shareholders  
(60.3)
Other comprehensive (loss)/ income  
Share of joint venture Other comprehensive loss  
Total comprehensive (loss)/ income  
5
-
(0.6)
(60.3)
190.1
Net (loss)/ income attributable to common shareholders  
per share  
Basic  
14  
14  
(0.13)
(0.13)
0.40
0.40
Diluted  
Weighted average number of shares outstanding for the purpose  
of calculating earnings per share  
Basic  
14  
14  
474,366,637
474,366,637
473,332,153
477,361,286
Diluted  
The notes are an integral part of the consolidated financial statements.  
PAGE 44  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
CONSOLIDATED  
STATEMENTS OF EQUITY  
(Expressed in millions of United States dollars)  
December 31,  
2022  
December 31,  
2021  
For the years ended  
Note  
Share capital:  
11(B)  
Balance, beginning of the year  
Exercise of Share Options  
1,309.1
3.4
1,306.5
1.2
15  
15  
15  
11  
Settlement of Restricted Share Units  
Settlement of Performance Share Units  
Weighted average value of shares cancelled  
Balance, end of the year  
1.2
0.9
1.9
0.5
(47.9)
1,267.7
-
1,309.1
Contributed surplus:  
Balance, beginning of the year  
Share-based compensation  
Transfer to Deficit  
51.1
0.1
-
50.8
0.4
(0.1)
-
15  
Excess of weighted value of shares cancelled  
Balance, end of the year  
8.0
59.2
51.1
Treasury account:  
Balance, beginning of the year  
Shares purchased  
-
39.9
(39.9)
-
-
-
-
-
11  
11  
Shares cancelled  
Balance, end of the year  
Deficit:  
Balance, beginning of the year  
(412.2)
(23.8)
(60.3)
-
(610.7)
-
Dividends paid  
Net (loss)/ income attributable to common shareholders  
Transfer from Contributed surplus  
Amounts transferred from Accumulated other comprehensive income  
Balance, end of the year  
190.7
0.1
-
7.7
(496.3)
(412.2)
Accumulated other comprehensive income:  
Balance, beginning of the year  
Other comprehensive loss  
-
-
-
7.7
(0.6)
(7.7)
5
5
Amounts transferred to Deficit  
Amounts transferred to Statement of Net (Loss)/ Income and  
Comprehensive (Loss)/ Income  
-
-
0.6
-
Balance, end of the year  
Total equity attributable to common shareholders  
Balance, end of the year  
830.6
948.0
The notes are an integral part of the consolidated financial statements.  
PAGE 45  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
CONSOLIDATED  
STATEMENTS OF CASH FLOWS  
(Expressed in millions of United States dollars)  
December 31,  
December 31,  
2021  
2022  
For the years ended  
Note  
Cash flows generated by/ (used in):  
Operations:  
Net (loss)/ income for the year  
Adjustments for:  
(60.3)
190.7
Share-based compensation  
Share of profit from investment in joint venture  
Share of loss/ (income) from investments in associates  
Impairment of intangible exploration assets  
Finance income  
15  
5
9.5
(146.6)
8.2
6.3
(224.4)
(2.5)
-
6
7
170.6
(2.4)
3.5
13  
13  
(0.1)
18.3
0.7
Finance expense  
Other  
-
Changes in non-cash operating working capital  
22  
1.2
0.2
Net cash used in operating activities  
(16.3)
(10.8)
Investing:  
Intangible exploration expenditures  
Long-term loan provided to associated company  
Equity investment in associates  
7
17  
6
(3.3)
(2.0)
(4.6)
-
(24.8)
250.0
0.3
(2.0)
200.0
(5.7)
Dividends received from joint venture  
Changes in non-cash investing working capital  
5
22  
Net cash generated by investing activities  
220.2
187.7
Financing:  
Repayment of Term Loan  
10  
10  
10  
13  
13  
15  
11  
11  
15  
-
-
(141.0)
98.0
(98.0)
(18.3)
0.1
Drawdown of Corporate Facility  
Repayment of Corporate Facility  
Payment of interest, arrangement fees and other loan fees  
Receipt of interest income  
-
(3.5)
2.4
Settlement of Performance and Restricted Share Units  
Dividends paid to shareholders  
Repurchase of share capital  
(1.7)
(23.8)
(39.9)
3.3
(0.4)
-
-
Exercise of Share Options  
1.1
Net cash used in financing activities  
(63.2)
(158.5)
Effect of exchange rate changes on cash and cash equivalents  
denominated in foreign currency  
0.1
-
Increase in cash and cash equivalents  
140.8
58.9
18.4
40.5
Cash and cash equivalents, beginning of the year  
4
4
Cash and cash equivalents, end of the year  
199.7
58.9
The notes are an integral part of the consolidated financial statements.  
PAGE 46  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED  
FINANCIAL STATEMENTS  
For the years ended December 31, 2022, and December 31, 2021  
(Expressed in millions of United States dollars unless otherwise indicated)  
1. Incorporation
and nature of business:  
Africa Oil Corp. (collectively with its subsidiaries, “AOC” or the “Company”) was incorporated on March 29, 1993, under the laws of
British Columbia and is an international oil and gas exploration and production company based in Canada with oil and gas interests in
Africa. The Company’s registered address is Suite 2000 - 885 West Georgia St. Vancouver, BC, Canada V6C 3E8.
2. Basis
of preparation:  
A. Statement
of compliance:  
The Company prepares its consolidated financial statements in accordance with International Financial Reporting Standards (“IFRS”) as  
issued by the International Accounting Standards Board (“IASB”). The policies applied in these consolidated financial statements are  
based on IFRS issued and outstanding as at February 27, 2023, the date the Board of Directors approved the statements.  
B. Basis
of measurement:  
The consolidated financial statements have been prepared on the historical cost basis. Where there are assets and liabilities calculated  
on a different basis, this fact is disclosed in the relevant accounting policy.  
C. Functional
and presentation currency:  
These consolidated financial statements are presented in United States (US) dollars. The functional currencies of the Company’s  
individual entities are US dollars which represents the currency of the primary economic environment in which the entities operate.  
The consolidated financial statements are expressed in millions of US dollars unless otherwise indicated. The consolidated financial  
statements were previously expressed in thousands of US dollars and as a result of the change, the Company has also presented the  
opening balance sheet for the comparative period in millions of US dollars.  
D. Use
of estimates and judgements:  
The preparation of financial statements in conformity with IFRS requires management to make judgements, estimates and assumptions  
that affect the application of accounting policies and the reported amounts of assets, liabilities, income and expenses. Actual results  
may differ from these estimates.  
Information about significant areas of estimation and critical judgements in applying accounting policies that have the most significant  
effect on the amounts recognized in the consolidated financial statements are noted below, with further details of the assumptions  
contained in the relevant note. The Company has a 50% interest in Prime, which is a key asset for the Company. Information about  
Prime’s reserve and resource estimates has been included.  
i. Exploration
and evaluation costs:  
Exploration and evaluation costs are initially capitalized as intangible exploration assets with the intent to establish commercially  
viable reserves. The Company is required to make significant estimates and judgements about the future events and circumstances  
regarding whether the carrying amount of intangible exploration assets exceeds its recoverable amount (see note 7).  
The carrying amounts of the Company’s exploration and evaluation costs are reviewed at each reporting date to determine whether  
there is any indication of impairment. Exploration and evaluation assets are assessed for impairment if facts and circumstances  
suggest that the carrying amount exceeds the recoverable amount. Should the carrying amount exceed the recoverable amount,  
an impairment loss is recognized.  
Significant assumptions developed by management used to determine the recoverable amount of the cash generating unit (“CGU”)  
include estimates for the quantity of contingent resources, future commodity prices, production forecasts, operating expenses,  
development costs, the likelihood of a successful farm out process, the timing of financial investment decision (“FID”) and the  
discount rate. The contingent resources and production rates are prepared by the Company’s independent petroleum engineers  
(management’s experts). CGU’s are assets that are grouped together into the smallest group of assets that generates cash inflows  
from continuing use that are largely independent of the cash inflows of other assets or groups of assets.  
Exploration and evaluation assets are assessed if facts and circumstances suggest that an impairment loss recognized in prior  
periods may no longer exist or may have decreased. An impairment reversal is recognized if there has been an increase in the  
asset’s recoverable amount since the last impairment loss was recognized.  
The changing worldwide demand for energy and the global advancement of alternative sources of energy could result in a change  
in the assumptions used to determine the recoverable amount and could affect estimating the future cash flows which could impact  
the carrying amount of the Company’s intangible exploration assets. The timing of when global energy markets transition from  
carbon-based sources to alternative energy sources is highly uncertain. Environmental considerations are built into our estimates  
through the use of significant assumptions in estimating fair value including future commodity prices and discount rates. The  
PAGE 47  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
energy transition could impact the future prices of commodities and discount rates used to appraise oil and gas projects. Pricing  
assumptions used in the determination of recoverable amounts incorporate market expectations and the evolving worldwide  
demand for energy.  
ii. Share
based compensation:  
Charges for share purchase options are based on the fair value at the date of the award. Share purchase options are valued using  
the Black-Scholes model, and inputs to the model include assumptions on share price volatility, discount rates and expected life  
outstanding (see note 15).  
The estimated fair value of Performance share units (“PSUs”) is calculated based on non-market performance conditions set by  
the Company which are initially determined at the time of grant. The Company assesses the progress of reaching the individual  
performance conditions during each reporting period. PSUs cliff vest three years from the date of grant, at which time the Board  
of Directors will assign a performance multiple ranging from nil to 200% to determine the ultimate vested number of PSUs. The  
awards are revalued every quarter based on the Company’s share price and an estimate of the performance conditions at the  
quarter end. It is anticipated that PSU settlements will be made by issuing shares from treasury or cash, at the discretion of the  
Board of Directors (see note 15).  
The estimated fair value of the Restricted share units (“RSUs”) is initially determined at the time of grant. The awards are revalued  
every quarter based on the Company’s share price. RSUs may be settled in shares issued from treasury or cash, at the discretion  
of the Board of Directors (see note 15).  
iii. Consolidation
of entities:  
When assessing control over a subsidiary, the Company is required to consider the nature of its relationship with the subsidiary,  
and whether strategic and operating decisions made by the subsidiary are made independently without the significant influence  
or control of the Company. Factors considered when assessing for control include share ownership, board composition and  
management involvement in the business.The determination of whether strategic and operating decisions made by the Company’s  
subsidiaries (see note 18) are made independently without the significant influence or control of the Company requires judgement.  
iv. Valuation
of investments:  
An investment in an associate or a joint venture is accounted for using the equity method from the date on which the investee  
becomes an associate or a joint venture. Investments in associates or joint ventures are initially recorded at cost. On acquisition  
of the investment in an associate or a joint venture, any excess of the cost of the investment over the share of the net fair value  
of the identifiable assets and liabilities of the investee is recognized as notional goodwill, which is included within the carrying  
amount of the investment. Significant assumptions developed by management used to determine the fair value of the non-current  
assets include estimates for the quantity of proved and probable petroleum reserves, future commodity prices, operating and  
capital costs as well as discount rates. The proved and probable petroleum reserves are prepared by the investee’s independent  
petroleum engineers (management’s experts).  
Where contingent consideration has been recognized in an investment in an associate or joint venture, any revisions to the  
contingent consideration estimates after the date of acquisition, which have been considered as changes in estimates in accordance  
with IAS 8, are accounted for on a prospective basis. Any change in the liability as a result of the revised cash flows is adjusted to  
the cost of the asset and, in accordance with paragraph 37 of IAS 8, recognized as part of the associate or joint venture carrying  
amount rather than in profit or loss.  
v. Impairment
of joint ventures and associates:  
The amounts for investments in joint ventures and associates represents the Company’s equity interest in other entities, where there  
is either joint control or significant influence. The Company assesses investments in joint ventures and associates for impairment  
whenever changes in circumstances or events indicate that the carrying value may not be recoverable. The process of determining  
whether there is an indicator for impairment or calculating the recoverable amount requires judgement.  
An area in which the Company has applied judgement in the prior year relates to the investment in Prime. On acquisition,  
judgements and estimates were used in determining fair values on acquisition for the purposes of the notional purchase price  
allocation. Subsequently, in assessing whether there are any indicators of impairment the Company has considered any effects  
of Prime’s forward sales, the loan facility, and any operational and contractual implications on the future dividend stream when  
assessing for impairment indicators.  
vi. Deferred
tax asset:  
A deferred tax asset is recognized to the extent that it is probable that future taxable profits will be available against which the  
temporary difference can be utilized. Deferred tax assets are reviewed at each reporting date and are reduced to the extent that it  
is probable that the related tax benefit will no longer be realized.  
vii. Contingencies:  
Contingencies are subject to measurement uncertainty as the related financial impact will only be confirmed by the outcome of a  
future event. The assessment of contingencies requires the application of judgements and estimates including the determination  
of whether a present obligation exists, and the reliable estimation of the timing and amount of cash flows required to settle the  
contingencies.  
viii. Hydrocarbon reserve and resource estimates:  
Oil and gas production assets are depreciated on a units-of-production (“UoP”) basis at a rate calculated by reference to total  
proved and probable oil and gas reserves (“2P”) determined in accordance with the principles contained in the SPE Petroleum  
Resources Management Reporting System (“PRMS”) framework. Facilities included in oil and gas production assets are depreciated  
on a straight-line basis over the economic useful life of the field.  
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Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
Prime estimates its 2P reserves based on information provided by reputable independent petroleum engineers, either directly in  
cases where Prime acts as operator, or indirectly, through the information provided by the respective operators. This information  
from reputable independent petroleum engineers concerns, amongst others, the geological and technical data on the size, depth,  
shape and grade of the hydrocarbon body and suitable production techniques and recovery rates.  
2P reserves are determined using estimates of oil and gas in place, recovery factors, operating expenses, future development costs  
and future commodity prices; the latter having an impact on the total amount of recoverable reserves and the proportion of the  
gross reserves which are attributable to the host government under the terms of the Production-Sharing Agreements.  
The current long-term Brent oil price assumption used in the estimation of proved and probable reserves is based on the long-term  
oil price forward curve of Bloomberg L.P.  
As the economic assumptions used may change and, as additional geological information is obtained during the operation of a  
field, estimates of recoverable reserves may change.  
ix. Provision
for site restoration:  
Amounts used in recording a provision for site restoration are based on current legal and constructure requirements and current  
technology and price levels for the removal of facilities and plugging and abandoning of wells. Due to changes in relation to these  
items, the future cash outflows in relation to the site decommissioning and restoration can be difficult. To reflect the effects due to  
changes in legislation, requirements, technology and price levels, the carrying amounts of site restoration provisions are reviewed  
on a regular basis.  
On fields where the Group is required to contribute to site restoration costs, a provision is recorded to recognize the future  
commitment. An asset is created, as part of oil and gas interests, to represent the discounted value of the anticipated site restoration  
liability and depleted over the life of the field on a unit of production basis. The corresponding accounting entry to the creation of  
the asset recognizes the discounted value of the future liability. The discount applied to the anticipated site restoration liability is  
subsequently released over the life of the field and is charged to finance expense. Changes in site restoration costs and reserves  
are treated prospectively and consistent with the treatment applied upon initial recognition (see note 9).  
x. Uncertain
tax positions:  
Contingencies are subject to measurement uncertainty as the related financial impact will only be confirmed by the outcome of a  
future event. The assessment of contingencies requires the application of judgements and estimates including the determination  
of whether a present obligation exists and the reliable estimation of the timing and amount of cash flows required to settle the  
contingency. The
Company is subject to income taxes in numerous legal jurisdictions. Accounting for income taxes requires the  
Company to interpret frequently changing laws and regulations, including changing income tax rates, and make certain judgements  
with respect to the application of tax law, estimating the timing of temporary difference reversals, and estimating the realizability  
of tax assets. There are many transactions and calculations for which the ultimate tax determination is uncertain. The Company  
recognizes a liability for a tax filing position based on its assessment of the probability that additional taxes may ultimately be due.  
3. Significant
accounting policies:  
The accounting policies set out below have been applied consistently to all years presented in these consolidated financial statements  
and have been applied consistently by the Company and its subsidiaries.  
A. Basis
of consolidation:  
i. Subsidiaries:  
Subsidiaries are entities controlled by the Company. Control exists when the Company has the power to govern the financial  
and operating policies of an entity so as to obtain benefits from its activities. In assessing control, potential voting rights that are  
currently exercisable are taken into account. The financial statements of subsidiaries are included in the consolidated financial  
statements from the date that control commences until the date that control ceases.  
The acquisition method of accounting is used to account for acquisitions of subsidiaries and assets that meet the definition of a  
business under IFRS. The cost of an acquisition is measured as the fair value of the assets given, equity instruments issued, and  
liabilities incurred or assumed at the date of exchange.  
Identifiable assets acquired and liabilities and contingent liabilities assumed in a business combination are measured initially at  
their fair values at the acquisition date. The fair value of property, plant and equipment and intangible exploration assets recognized  
in a business combination, is based on market values. The excess of the cost of acquisition over the fair value of the identifiable  
assets, liabilities and contingent liabilities acquired is recorded as goodwill.
If the cost of acquisition is less than the fair value of  
the net assets of the subsidiary acquired, the difference is recognized immediately in the Statement of Net (Loss)/ Income and  
Comprehensive (Loss)/ Income.  
ii. Jointly
controlled operations and jointly controlled assets:  
Many of the Company’s oil and natural gas activities involve jointly controlled assets. The consolidated financial statements include  
the Company’s share of these jointly controlled assets and liabilities and a proportionate share of the relevant revenue and related  
costs.  
iii. Transactions
eliminated on consolidation:  
Intercompany balances and transactions, and any unrealized income and expenses arising from intercompany transactions, are  
eliminated in preparing the consolidated financial statements.  
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Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
B. Equity
method:  
Investments in joint ventures and associates are accounted for using the equity method. Investments of this nature are recorded at  
original cost. Investments in joint ventures or associates which arise from a loss in control of a subsidiary are recorded at fair value on  
the date of the loss of control. The investment is adjusted at each reporting date for the Company’s share of the profit or loss of the  
investment after the date of acquisition. The investor’s share of the profit or loss of the investee is also recognized in the Company’s  
Statement of Net (Loss)/ Income and Comprehensive (Loss)/ Income. Distributions received reduce the carrying amount of the  
investment.  
The Company assesses investments in joint ventures and associates for impairment whenever changes in circumstances or events  
indicate that the carrying value may not be recoverable. If such impairment indicators exist, the carrying amount of the investment is  
compared to its recoverable amount. The recoverable amount is the higher of the investment’s fair value less costs to sell and its value  
in use. The investment is written down to its recoverable amount when its carrying amount exceeds the recoverable amount.  
The Company has a 50% interest in Prime which is a key asset for the Company. The most significant accounting policies for Prime are  
as follows:  
i. Sales
of crude oil and natural gas:  
Revenue from the sale of crude oil and natural gas is recognized when control of the goods transfers to the customer. The transfer  
of control of the crude oil and natural gas sold by Prime usually coincides with title passing to the customer and the customer  
taking physical possession. This generally occurs when the product is physically transferred into a vessel, pipe or other delivery  
mechanism.  
Crude oil transaction prices under fixed forward contracts are based on the agreed contract price plus or minus a premium based  
on an arithmetical average of the mean in quoted market prices for the previous month of the bill of lading. The performance  
obligation is satisfied and payment is due upon delivery, FOB, to the buyer. At this point in time, at the bill of lading date, a trade  
receivable is recognized and there are generally 30 days between revenue recognition and payment. There are no obligations for  
returns, refunds, warranties nor other obligations when control has been transferred.  
Prime principally satisfies its performance obligations at a point in time and the amounts of revenue recognized relating to  
performance obligations satisfied over time are not significant.  
Revenue from crude oil transactions not covered under fixed forward contracts, arises from the production and lifting of crude oil  
on an ‘entitlements’ basis. Under the entitlement’s method, revenue reflects Prime’s share of production under the terms of the  
relevant production sharing contracts, regardless of which participant has actually made the sale and invoiced the production. This  
is achieved by applying the following approach in dealing with imbalances between actual sales and entitlements.  
Crude oil entitlement underlifts are recognized at the market price of oil at the balance sheet date. The excess of product sold  
during the period over the participant’s ownership share of production is recognized by Prime (acting as underlifter) as an asset in  
trade and other receivables with a corresponding credit to cost of sales. Prime’s underlift receivable is the right to receive additional  
oil from future production without the obligation to fund the production of that additional oil.  
Crude oil entitlement overlifts are treated as a purchase of crude oil by the overlifter from the underlifter and are also recognized at  
the market price of oil at the balance sheet date.The excess of product purchased during the period over the participant’s ownership  
share of production is recognized by Prime (acting as overlifter) as a liability in trade and other payables with a corresponding  
charge to cost of sales. An overlift liability is the obligation to deliver oil out of Prime’s equity share of future production.  
Revenues resulting from the production of oil under Production Sharing Contracts (“PSCs”) is recognized for those amounts relating  
to Prime’s cost recoveries and Prime’s share of the remaining production. Sales between group companies are based on prices  
generally equivalent to commercially available prices.  
ii. Tax
oil revenue:  
According to the production-sharing agreements (“PSAs”), the share of the profit oil (“PPT”) to which the government is entitled  
in any calendar year, in accordance with the PSA, is deemed to include a portion representing the corporate income tax imposed  
upon and due by Prime. As the tax oil lifted by the operator on behalf of Prime is sold to 3rd party customers and proceeds are  
used to settle Prime’s tax liabilities, this share of PPT is considered to be within the scope of IFRS 15, ‘Revenue from contracts with  
customers’. Consequently, this portion of income tax and revenue is presented gross in profit and loss. Investment tax credit utilized  
is recognized as ‘Other operating income’.  
iii. Depreciation/amortization:  
Oil and gas properties are depreciated/amortized from the commencement of production, on a UoP basis, which is the ratio of oil  
and gas production in the period to the estimated quantities of the 2P reserves at the end of the period plus the production in the  
period, on a field-by-field basis. Facilities included in oil and gas production assets are depreciated on a straight-line basis over  
the economic useful life of the field concerned. Costs used in the UoP calculation and straight-line depreciation comprise the net  
carrying amount of capitalized costs plus the estimated future field development costs. Changes in the estimates of reserves or  
future field development costs are dealt with prospectively. Oil and gas volumes are considered produced once they have been  
measured through meters at custody transfer or sales transaction points at the outlet valve on the field storage tank. Rights and  
concessions are depleted on the UoP basis over the total proved and probable reserves of the relevant area.  
iv. Recoverability
of oil and gas properties:  
Prime assesses each asset or cash generating unit (CGU) (excluding goodwill, which is assessed annually regardless of indicators)  
each reporting period to determine whether any indication of impairment exists. Where an indicator of impairment exists, with  
reference to total proved and risk-adjusted probable reserves (‘2P’), a formal estimate of the recoverable amount is made, which is  
considered to be the higher of the fair value less costs to sell and value in use. The assessments require the use of estimates and  
PAGE 50  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
assumptions such as long-term oil prices (considering current and historical prices, price trends and related factors), discount rates,  
operating costs, future capital requirements, decommissioning costs, exploration potential, reserves (see Hydrocarbon reserve  
and resource estimates above) and operating performance (which includes production and sales volumes). These estimates and  
assumptions are subject to risk and uncertainty. Therefore, there is a possibility that changes in circumstances will impact these  
projections, which may impact the recoverable amount of assets and/or CGUs.  
Fair value is determined as the amount that would be obtained from the sale of the asset in an arm’s length transaction between  
knowledgeable and willing parties. Fair value for oil and gas properties is generally determined as the present value of estimated  
future cash flows arising from the continued use of the assets, which includes estimates such as the cost of future expansion  
plans and eventual disposal, using assumptions that an independent market participant may take into account. Cash flows are  
discounted to their present value using a discount rate that reflects current market assessments of the time value of money and the  
risks specific to the asset/CGU.  
C. Long-term
debt:  
Long-term debt is initially measured at fair value less transaction costs that are directly attributable to the acquisition or issue of the  
debt. Subsequently, long-term debt is measured at amortized cost using the effective interest method. Long-term debt is classified as  
current if the liability is due to be settled within twelve months from the reporting date. All other debt is classified as non-current.  
D. Foreign
currency:  
Monetary assets and liabilities denominated in foreign currencies are translated into US dollars at exchange rates prevailing at the  
balance sheet date and non-monetary assets and liabilities are translated at rates in effect on the date of the transaction. Revenues and  
expenses are translated at exchange rates at the date of transaction. Exchange gains or losses arising from translation are included in  
the Statement of Net (Loss)/ Income and Comprehensive (Loss)/ Income.  
E. Intangible
exploration assets:  
i. Pre-exploration
expenditures:  
Costs incurred prior to obtaining the legal rights to explore an area are recognized in the Statement of Net (Loss)/ Income and  
Comprehensive (Loss)/ Income
as incurred.  
ii. Exploration
expenditures:  
Exploration expenditures include costs associated with the acquisition of a license interest, directly attributable general and  
administrative costs, expenditures incurred in the process of determining oil and gas exploration targets, and exploration drilling  
costs. All exploration expenditures with common geological structures and shared infrastructure are accumulated together within  
intangible exploration assets. The Company does not aggregate exploration expenditures above the segment level for the purpose  
of impairment testing. Costs are not depleted until such time as the exploration phases on the license area are complete, the  
license area is relinquished, or commercially viable reserves have been discovered and extraction of those reserves is determined  
to be technically feasible.  
If commercial reserves are established and technical feasibility for extraction demonstrated, then the related capitalized intangible  
exploration costs are transferred into a CGU within oil and gas interests subsequent to determining that the assets are not impaired  
(see “Impairment” below). Where results of exploration drilling indicate the presence of hydrocarbons which are ultimately not  
considered commercially viable, all related costs are recognized in the Statement of Net (Loss)/ Income and Comprehensive (Loss)/  
Income.  
Net proceeds from any disposal or farmout of an intangible exploration asset are recorded as a reduction in intangible exploration  
assets.  
iii. Development
and production costs:  
All costs incurred after the technical feasibility and commercial viability of producing hydrocarbons has been demonstrated are  
capitalized within oil and gas interests on a CGU basis. Subsequent expenditures are capitalized only where it either enhances  
the economic benefits of the development/producing asset or replaces part of the existing development/producing asset. Any  
remaining costs associated with the part replaced are expensed in the Statement of Net (Loss)/ Income and Comprehensive (Loss)/  
Income.  
Net proceeds from any disposal of oil and gas interests are recorded as a gain or loss on disposal recognized in the Statement of  
Net (Loss)/ Income and Comprehensive (Loss)/ Income to the extent that the net proceeds exceed or are less than the appropriate  
portion of the net capitalized costs of the asset.  
F. Depreciation:  
For property and equipment, depreciation is recognized in the Statement of Net (Loss)/ Income and Comprehensive (Loss)/ Income  
on a straight-line basis over the estimated useful lives of each part of an item of property and equipment. Land is not depreciated.
The  
estimated useful lives for other property and equipment, consisting of primarily office and computer equipment, for the current and  
comparative years are from one to three years.  
G. Impairment:  
i. Financial
assets carried at amortized cost:  
A financial asset is assessed at each reporting date to determine whether there is any objective evidence that it is impaired. A  
financial asset is considered to be impaired if objective evidence indicates that one or more events have had a negative effect on  
the estimated future cash flows of that asset.  
PAGE 51  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
The Company recognizes loss allowances for expected credit losses (“ECLs”) on its financial assets measured at amortized cost.  
Due to the nature of its financial assets, the Company measures loss allowances at an amount equal to expected lifetime ECLs.  
An impairment loss in respect of a financial asset measured at amortized cost is calculated as the difference between its carrying  
amount and the present value of the estimated future cash flows discounted at the original effective interest rate.  
Individually significant financial assets are tested for impairment on an individual basis. The remaining financial assets are assessed  
collectively in groups that share similar credit risk characteristics.  
All impairment losses are recognized in the Statement of Net (Loss)/ Income and Comprehensive (Loss)/ Income.  
An impairment loss is reversed if the reversal can be related objectively to an event occurring after the impairment loss was  
recognized. For financial assets measured at amortized cost the reversal is recognized in the Statement of Net (Loss)/ Income and  
Comprehensive (Loss)/ Income.  
ii. Non-financial
assets:  
The carrying amounts of the Company’s non-financial assets, including the Company’s equity investments, other than intangible  
exploration assets and deferred tax assets, are reviewed at each reporting date to determine whether there is any indication of  
impairment or reversals of impairment. Intangible exploration assets are assessed for impairment when they are reclassified to  
property and equipment, as oil and gas interests, and also if facts and circumstances suggest that the carrying amount exceeds  
the recoverable amount. If any such indication exists, then the asset’s recoverable amount is estimated. For goodwill and other  
intangible assets that have indefinite lives or that are not yet available for use, an impairment test is completed each year.  
For the purpose of impairment testing, assets are grouped together into a CGU. The recoverable amount of an asset or a CGU is  
the greater of its value in use and its fair value less costs of disposal.  
In assessing value in use, the estimated future cash flows are discounted to their present value using a post-tax discount rate  
that reflects current market assessments of the time value of money and the risks specific to the asset. Value in use is generally  
computed by reference to the present value of the future cash flows expected to be derived from production of 2P reserves. In  
determining fair value less costs of disposal, recent market transactions are taken into account, if available, and a post-tax discount  
rate is applied. In the absence of such transactions, an appropriate valuation model is used.  
An impairment loss is recognized if the carrying amount of an asset or its CGU exceeds its estimated recoverable amount.  
Impairment losses are recognized in the Statement of Net (Loss)/ Income and Comprehensive (Loss)/ Income. Impairment losses  
recognized in respect of CGU’s are allocated first to reduce the carrying amount of any goodwill allocated to the units and then to  
reduce the carrying amounts of the other assets in the unit (group of units) on a pro rata basis.  
If there is an indicator that a previous impairment may no longer exist or may have decreased, the recoverable amount of the  
relevant asset or its CGU is calculated and compared against the carrying amount. The impairment is reversed to the extent that the  
asset or its CGU’s recoverable amount does not exceed the carrying amount that would have been determined if no impairment  
had been recognized. An impairment reversal is recognized in the Statement of Net (Loss)/ Income and Comprehensive (Loss)/  
Income.  
H. Share
purchase options:  
The Company has a stock option plan (see note 15).
The Company uses the fair value method, utilizing the Black-Scholes option  
pricing model, for valuing share purchase options granted to directors, officers, consultants and employees.
The estimated fair value  
is recognized over the applicable vesting period, commencing from the date of employee service, as stock-based compensation  
expense and an increase to contributed surplus.
A forfeiture rate is estimated on the grant date and is adjusted to reflect the actual  
number of options that vest.
When the share purchase options are exercised, the proceeds received are credited to share capital.  
I. Performance
share units (“PSUs”):  
The Company has a long-term incentive plan (see note 15). Eligible plan participants may be granted PSUs. PSUs are accounted  
for as share-based awards. The estimated fair value of the awards is calculated based on non-market performance conditions set  
by the Company which are initially determined at the time of grant. The Company assesses the progress of reaching the individual  
performance conditions during each reporting period. PSUs cliff vest three years from the date of grant and the estimated fair value of  
the grant will be expensed evenly throughout the remaining vesting period. PSUs may be settled in shares issued from treasury or cash,  
at the discretion of the Board of Directors.  
J. Restricted
share units (“RSUs”):  
The Company has a long-term incentive plan (see note 15). Eligible plan participants may be granted RSUs. RSUs are accounted for  
as cash-based awards and recorded as a liability. The estimated fair value of the awards is initially determined at the time of grant. The  
awards are revalued every quarter based on the Company’s share price and the change is recorded as share-based compensation  
in the Statement of Net (Loss)/ Income and Comprehensive (Loss)/ Income. RSUs granted to Non-Executive Directors cliff vest three  
years from the date of grant. RSUs granted to all other eligible plan participants vest over three years (1/3 on the first, second and third  
anniversary of grant). The estimated fair value of RSUs are expensed evenly throughout the remaining vesting period. RSUs may be  
settled in shares issued from treasury or cash, at the discretion of the Board of Directors.  
K. Finance
income and expenses:  
Finance income and expenses are recognized as it accrues in the Statement of Net (Loss)/ Income and Comprehensive (Loss)/ Income,  
using the effective interest method.  
PAGE 52  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
L. Income
tax:  
Income tax expense comprises current and deferred tax. Income tax expense is recognized in the Statement of Net (Loss)/ Income and  
Comprehensive (Loss)/ Income except to the extent that it relates to items recognized directly in equity, in which case it is recognized  
in equity.  
Current tax is the expected tax payable on the taxable income for the year, using tax rates enacted or substantively enacted at the  
reporting date, and any adjustment to tax payable in respect of previous years.  
Deferred tax is recognized using the balance sheet method, providing for temporary differences between the carrying amounts of  
assets and liabilities for financial reporting purposes and the amounts used for taxation purposes. Deferred tax is not recognized on the  
initial recognition of assets or liabilities in a transaction that is not a business combination. In addition, deferred tax is not recognized for  
taxable temporary differences arising on the initial recognition of goodwill. Deferred tax is measured at the tax rates that are expected  
to be applied to temporary differences when they reverse, based on the laws that have been enacted or substantively enacted by the  
reporting date. Deferred tax assets and liabilities are offset if there is a legally enforceable right to offset, and they relate to income taxes  
levied by the same tax authority on the same taxable entity, or on different tax entities, but they intend to settle current tax liabilities and  
assets on a net basis, or their tax assets and liabilities will be realized simultaneously.  
A deferred tax asset is recognized to the extent that it is probable that future taxable profits will be available against which the temporary  
difference can be utilized. Deferred tax assets are reviewed at each reporting date and are reduced to the extent that it is no longer  
probable that the related tax benefit will be realized.  
M. Earnings
per share:  
Basic earnings per share is calculated by dividing net income/(loss) attributable to the common shareholders by the weighted average  
number of common shares outstanding during the year. Diluted earnings per share is determined by adjusting the net income/  
(loss) attributable to the common shareholders and the weighted average number of common shares outstanding for the effects of  
dilutive instruments such as options and LTIP’s granted to employees. The weighted average number of diluted shares is calculated  
in accordance with the treasury stock method. The treasury stock method assumes that the proceeds received from the exercise of all  
potentially dilutive instruments are used to repurchase common shares at the average market price. The PSUs are considered to be  
contingently issuable and are included in the calculation of diluted EPS as if the conditions of the contingency are deemed to have  
been met based on the information available at the end of the reporting period.
PSUs are only included in the diluted EPS calculation  
if the effect is dilutive. RSUs are included in full in the diluted EPS calculation only if the effect is dilutive.  
N. Financial
instruments:  
Financial assets and liabilities are recognized when the Company becomes a party to the contractual provisions of the instrument.  
Financial assets are derecognized when the rights to receive cash flows from the assets have expired or have been transferred and the  
Company has transferred substantially all risks and rewards of ownership. Financial assets and liabilities are offset and the net amount  
is reported in the Balance Sheet when there is a legally enforceable right to offset the recognized amounts and there is an intention to  
settle on a net basis or realize the asset and settle the liability simultaneously.  
At initial recognition, the Company classifies its financial instruments either as fair value through profit and loss, fair value through other  
comprehensive income or at amortized cost depending on the purpose for which the instruments were acquired. The Company only  
has instruments recognized at amortized cost.  
i. Financial
assets and liabilities at amortized cost:  
Financial assets and liabilities at amortized cost include accounts receivable, loans receivable, accounts payables and debt and  
are initially recognized at the amount required to be received or paid, less, when material, a discount to reduce the receivables or  
payables to fair value. Subsequently, these assets and liabilities are measured at amortized cost using the effective interest method.  
Financial assets and liabilities are classified as current assets and liabilities if payment is due within twelve months. Otherwise, they  
are presented as non-current assets and liabilities.  
O. Provisions:  
A provision is recognized if, as a result of a past event, the Company has a present legal or constructive obligation that can be estimated  
reliably, and it is probable that an outflow of economic benefits will be required to settle the obligation. Provisions are determined by  
discounting the expected future cash flows at a pre-tax rate that reflects current market assessments of the time value of money and the  
risks specific to the liability. Provisions are not recognized for future operating losses.  
i. Contingent
Consideration:  
Contingent consideration formed part of the overall consideration for the acquisition of Prime. At the date of acquisition, an  
estimate of the contingent consideration is determined and included as part of the cost of the acquisition.  
Subsequent to acquisition, contingent consideration can be treated using two acceptable methods, the cost-based approach and  
the fair value-based approach. The Company have determined the cost-based approach to give the best estimate of the value of  
the contingent consideration. Any revisions to the contingent consideration estimates after the date of acquisition, are accounted  
for as changes in estimates in accordance with IAS 8, to be accounted for on a prospective basis. The change in the liability, as a  
result of the revised cash flows, would be adjusted to the cost of the investment and, in accordance with paragraph 37 of IAS 8,  
recognized as part of the investment’s carrying amount rather than in profit or loss.  
The estimates involved in assessing the value of the contingent consideration include the expected timing of payments, the  
expected settlement value, the likelihood of settlement and the probability of the assessed outcomes occurring. There is significant  
judgement used in the determination of these estimates.  
PAGE 53  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
ii. Provision
for site restoration:  
On fields where the Group is required to contribute to site restoration costs, a provision is recorded to recognize the future  
commitment. An asset is created, as part of oil and gas interests, to represent the discounted value of the anticipated site restoration  
liability and depleted over the life of the field on a unit of production basis. The corresponding accounting entry to the creation of  
the asset recognizes the discounted value of the future liability. The discount applied to the anticipated site restoration liability is  
subsequently released over the life of the field and is charged to finance expense. Changes in site restoration costs and reserves  
are treated prospectively and consistent with the treatment applied upon initial recognition.  
4. Cash
and cash equivalents:  
December 31,  
December 31,  
As at  
2022  
2021  
199.3  
58.5  
Cash and cash equivalents  
0.4  
0.4  
Restricted cash  
199.7  
58.9  
Restricted cash consists of the Company’s cash balances that are held in joint venture bank accounts.  
Cash equivalents include short-term deposits made for varying periods of between one day and three months, depending on the  
immediate cash requirements of the Group, and earn interest at varying rates.  
5. Equity
investment in joint venture:  
Prime Oil and Gas Coöperatief U.A. (“Prime”):  
On January 14, 2020, the Company completed the acquisition of a 50% ownership interest in Prime. BTG Pactual Holding S.à.r.l., a  
private limited liability company governed and existing under the laws of the Grand Duchy of Luxembourg (“BTG”) continues to own  
the remaining 50% of Prime. The Company has accounted for the acquisition as a joint venture as there is joint control.  
Prime is incorporated in the Netherlands and its principal place of business is Nigeria. The primary assets of Prime are an indirect 8%  
interest in Oil Mining Lease (“OML”) 127 and an indirect 16% interest in OML 130. OML 127 is operated by affiliates of Chevron and  
cover part of the producing Agbami field. OML 130 is operated by affiliates of Total S.A. and contains the producing Akpo and Egina  
fields.  
In the year ended December 31, 2022, Prime made five dividend payments totaling $500.0 million gross, with a net payment to the  
Company of $250.0 million related to its 50% interest. In the year ended December 31, 2021, four dividend payments were made  
totaling $400.0 million gross, with a net payment to the Company of $200.0 million related to its 50% interest. The timing and payment  
of the dividends is discretionary. There are no restrictions on the ability of Prime to pay dividends to its members.  
The following table shows the Company’s carrying value of the investment in Prime as at December 31, 2022, and December 31, 2021.  
December 31,  
December 31,  
2022  
2021  
Balance, beginning of the year  
617.1  
561.3  
Share of joint venture profit  
146.6  
224.4  
Revaluation of contingent consideration  
-
32.0  
Dividends received from Prime  
(250.0)  
(200.0)  
Share of joint venture other comprehensive loss  
-
(0.6)  
Balance, end of the year  
513.7  
617.1  
In the year ended December 31, 2022, the Company recognized income of $146.6 million relating to its investment in Prime (year  
ended December 31, 2021 - $224.4 million).  
On June 25, 2021, Prime signed a Securitization Agreement with Equinor ASA (“Equinor”) and Chevron, whereby Equinor agreed  
to pay a security deposit to the two other partners to secure future payments due under that Securitization Agreement, pending a  
comprehensive resolution being reached among all unit parties in respect of the tract participation in the Agbami field. In accordance  
with the Securitization Agreement, on June 29, 2021, Prime received from Equinor its portion of the security deposit in the form of  
a cash payment of $305.0 million. A provision for the full cash payment has been recorded within Prime to reflect the mechanism  
pursuant to which any such imbalance payments due from Equinor to Prime under the terms of any future agreement among the  
Agbami parties will be set-off against this security deposit. The parties will continue ongoing discussions in an attempt to seek final  
resolution of the formal redetermination of the Agbami tract participation.  
PAGE 54  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
Under the Prime Sale and Purchase Agreement completed on January 14, 2020, a deferred payment of $118.0 million, subject to  
adjustment, may be due to the seller contingent upon the timing and final OML 127 tract participation in the Agbami field. The  
signing of the Securitization Agreement by Prime has led to the Company reassessing its view of the likelihood of making a contingent  
consideration payment to the seller. The signing of the Securitization Agreement by Prime does not constitute a redetermination of the  
tract participation and therefore does not trigger the payment of a contingent consideration under the Sale and Purchase Agreement  
but, at the Company’s discretion, could trigger discussions with the seller. The outcome of this process is uncertain. In 2021, the  
Company recorded $32.0 million as contingent consideration and increased the Company’s investment in Prime. As at December 31,  
2022, the Company has determined that there was an indicator of impairment in relation to its investment in Prime arising from an  
impairment recognized by Prime. The impairment recognized by Prime has arisen mainly from a reduction in the recoverable reserves  
for the Egina field and an increase in the discount rate.  
The Company determined the recoverable amount of its investment in Prime by calculating the value in use derived from the discounted  
cash flow forecast of the dividend stream to be received from Prime. The results of the impairment test indicated that the recoverable  
amount was in excess of the carrying value.  
The following tables summarizes Prime’s financial information as at and for the years ended December 31, 2022, and December 31,  
2021.  
Prime’s Balance Sheet  
December 31,  
December 31,  
As at  
2022  
2021  
Cash and cash equivalents included in current assets (1)  
331.7  
517.9  
Other current assets  
301.7  
369.7  
Non-current assets (2)  
3,188.9  
3,433.7  
Other current liabilities  
(320.1)  
(291.4)  
Loans and borrowings included in current liabilities (3)  
(421.9)  
(523.8)  
Other non-current liabilities  
(637.2)  
(540.2)  
Loans and borrowings included in non-current liabilities (3)  
(360.4)  
(493.0)  
Deferred income tax liabilities included in non-current liabilities  
(1,055.3)  
(1,238.7)  
Net assets of Prime  
1,027.4  
1,234.2  
Percentage ownership  
50%  
50%  
Proportionate share of Prime's net assets  
513.7  
617.1  
(1) See
Prime’s Statement of Cash Flows for additional information on movements in cash and cash equivalents.  
(2) As
at December 31, 2022, the carrying value of non-current assets included a fair value adjustment of $643.1 million (at December 31, 2021  
- $623.3 million). These amounts were allocated to goodwill as part of the notional purchase price allocation.  
(3) In the year ended December 31, 2022, Prime has repaid $384.5 million of RBL and PXF debt and drew an additional amount of $150.0  
million of the PXF Facility, reducing its gross debt to $782.3 million (year ended December 31, 2021, Prime repaid $436.0 million of RBL debt  
and had drawn $150.0 million of the PXF Facility, reducing its gross debt to $1,016.8 million).  
PAGE 55  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
Prime’s Statement of Net Income and Other Comprehensive Income  
December 31,  
December 31,  
For the years ended  
2022  
2021  
Revenue (1)  
1,446.3  
1,220.3  
Depreciation, depletion and amortization  
(262.7)  
(303.4)  
Production costs  
(154.1)  
(165.1)  
Movement in underlift/overlift (2)  
(46.8)  
32.1  
Royalties  
(92.7)  
(105.7)  
Cost of sales  
(556.3)  
(542.1)  
Gross profit  
890.0  
678.2  
Other operating income (3)  
112.8  
355.4  
Exploration expenses  
(2.8)  
(3.9)  
Impairment (4)  
(82.3)  
-
Other operating costs (5)  
(64.6)  
(28.1)  
Finance income  
6.5  
0.4  
Finance costs (6)  
(74.6)  
(100.4)  
Profit before tax  
785.0  
901.6  
Tax (7)  
(485.6)  
(460.0)  
Total profit for the year  
299.4  
441.6  
Other comprehensive loss(8)  
-
(1.1)  
Total comprehensive income  
299.4  
440.5  
Proportionate share of Prime’s profit for the year  
149.7  
220.8  
Adjustments to share of Prime’s profit for the year (9)  
(3.1)  
3.6  
Total share of Prime’s profit for the year  
146.6  
224.4  
Proportionate share of Prime's other comprehensive loss  
-
(0.6)  
Proportionate share of Prime's net income  
146.6  
223.8  
(1) Included
in revenue are royalties paid in kind of $40.7 million in the year ended December 31, 2022 (year ended December 31, 2021 - $30.8  
million).  
(2) As at December 31, 2022, Prime was in a net underlift position, reduced from a larger net underlift position at December 31, 2021.  
This resulted in a charge of $46.8 million in the Statement of Net Income and Other Comprehensive Income for the year ended in December  
31, 2022.  
(3) For
some of its qualifying capital expenditure (“QCE”), Prime is entitled to claim an investment tax credit (“ITC”) at the rate of 50% of the QCE  
incurred, either wholly or exclusively or necessarily for the purposes of its petroleum operations. This is a Nigerian government tax credit  
which can be offset with Petroleum Profit Tax (“PPT”) and serves as an incentive for investments in the exploration of oil and gas in the deep  
offshore waters of Nigeria. Prime recognized investment tax credits of $112.3 million in the year ended December 31, 2022 (year ended  
December 31, 2021 – net credits of $349.3 million). During the year ended December 31, 2022, Prime exhausted its investment tax credit  
pool and additional credits have since been generated on capital expenditure incurred on qualifying assets.  
(4) Prime has recorded an impairment of $82.3 million for the year ended December 31, 2022 (year ended December 31, 2021 – nil). The  
impairment has arisen mainly from a reduction in the expected ultimate recovery of the Egina field following the incorporation of the results  
of the 4D seismic acquired in late 2021 as well as an increase in the discount rate.  
(5) Other operating costs include Prime’s administrative costs, sales costs, withholding tax on dividends paid and the NDDC Levy, which  
concerns the Niger Delta Development Commission imposed by a regulatory body in Nigeria to fund the sustainable development of the  
Niger Delta region.  
(6) In
the year ended December 31, 2022, finance costs of $74.6 million have been incurred (year ended December 31, 2021 - $100.4 million).  
Finance costs have decreased in the year ended December 31, 2022, and are primarily made up of interest expenses incurred on the RBL  
and PXF facilities and accretion expenses incurred on the decommissioning liability.  
(7) The
tax expense has increased as taxable profits, driven by an increase in the gross profit, have increased in the year ended December 31,  
2022.  
(8) The Company recognized other comprehensive losses in 2021 relating to its share of movements of the fair value of hedge instruments  
recognized in Prime. These instruments have been settled in full as at December 31, 2021, and therefore no movements have been  
recognized in the year ended December 31, 2022.  
(9) The
adjustment in the year ended December 31, 2022, represents an adjustment to prior years. The adjustment in the year ended December  
31, 2021, related to the fair value of hedges included in the investment value of Prime acquisition which were fully settled during the year  
ended December 31, 2021.  
PAGE 56  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
Supplementary information: Prime’s Statement of Cash Flows  
December 31,  
December 31,  
For the years ended  
2022  
2021  
Profit before tax  
785.0  
901.6  
Adjustments for:  
Depreciation, depletion and amortization  
262.7  
303.4  
Impairment  
82.3  
-
Finance costs, net  
68.1  
100.0  
Taxes paid  
(643.0)  
(494.5)  
Change in provisions  
(2.9)  
307.0  
Interest expense paid  
(51.3)  
(44.9)  
Cash generated in operating activities before working capital  
500.9  
1,072.6  
Changes in working capital  
Changes in trade receivables  
37.3  
(155.3)  
Changes in over/underlift balances  
46.8  
(32.1)  
Changes in other working capital balances  
4.5  
168.2  
Total changes in working capital  
88.6  
(19.2)  
Net cash generated from operating activities  
589.5  
1,053.4  
Expenditures on oil and gas properties  
(47.8)  
(50.5)  
Interest income received  
6.5  
0.4  
Net cash used in investing activities  
(41.3)  
(50.1)  
Payment of dividends to shareholders  
(500.0)  
(400.0)  
Repayment of third-party borrowings  
(384.5)  
(436.0)  
Drawdown of PXF Facility  
150.0  
150.0  
Payment on settlement of derivative financial instruments  
-
(30.6)  
Net cash used in financing activities  
(734.5)  
(716.6)  
Foreign exchange variation on cash and cash equivalents  
0.1  
(0.2)  
Total cash flow  
(186.2)  
286.5  
Cash and cash equivalents, beginning of the year  
517.9  
231.4  
Cash and cash equivalents, end of the year  
331.7  
517.9  
PAGE 57  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
6. Equity
investments in associates:  
The Company currently holds the following equity investments in associates:  
Africa Energy  
Eco (Atlantic)  
Impact Oil  
Corp.  
Oil and Gas Ltd  
and Gas Ltd  
Total  
Ownership at December 31, 2022  
19.7%  
15.0%  
30.9%  
Shares held at December 31, 2022  
276,982,414  
54,941,744  
287,565,860  
At January 1, 2021  
45.8  
12.9  
57.5  
116.2  
Share of income/ (loss) from equity investments  
4.4  
(0.5)  
(1.4)  
2.5  
Additional investment through private placement  
-
2.0  
-
2.0  
At December 31, 2021  
50.2  
14.4  
56.1  
120.7  
(9.3)  
Share of (loss)/ income from equity investments  
(3.7)  
(6.2)  
0.6  
Gain on dilution of equity investment  
0.1  
0.7  
0.3  
1.1  
Additional investment through private placement  
-
5.8  
19.0  
24.8  
At December 31, 2022  
137.3  
46.6  
14.7  
76.0  
In the year ended December 31, 2022, the Company recognized a total loss of $8.2 million (year ended December 31, 2021 – income  
of $2.5 million) mainly driven by the results of the Gazania-1 exploration well on Block 2B offshore South Africa, with both Africa Energy  
Corp and Eco (Atlantic) Oil and Gas Ltd holding a participating interest in this license.  
As at December 31, 2022, the Company has determined that there are no indicators of impairment for any of its equity investments in  
associates.  
A. Africa
Energy Corp. (“Africa Energy”):  
Africa Energy holds participating interests in exploration blocks located offshore South Africa.  
In the year ended December 31, 2022, the Company’s ownership interest in Africa Energy decreased from 19.8% to 19.7% due to the  
issue of shares in which the Company did not participate.  
As at December 31, 2022, the market value of the Company’s investment in Africa Energy is $37.8 million based on the share price of  
CAD 0.19 (as at December 31, 2021 - $54.3 million).  
The following table summarizes Africa Energy’s financial information for the years ended December 31, 2022, (based on preliminary  
figures) and December 31, 2021. The Company is not aware of any material changes to the financial information.  
Balance Sheet  
December 31,  
December 31,  
As at  
2022  
2021  
Cash and cash equivalents included in current assets  
7.1  
11.8  
Other current assets  
0.2  
0.4  
Non-current assets (1)  
229.3  
242.9  
Current liabilities  
(0.3)  
(1.6)  
Net assets of Africa Energy  
236.3  
253.5  
Percentage ownership (2)  
19.7%  
19.8%  
Proportionate share of Africa Energy’s net assets  
46.6  
50.2  
Statement of Net (loss)/ profit and comprehensive (loss)/ profit from continuing operations  
December 31,  
December 31,  
For the years ended  
2022  
2021  
Net (loss)/ profit and comprehensive (loss)/ profit from continuing operations  
(18.8)  
22.2  
Proportionate share of Africa Energy's net (loss)/ income  
(3.7)  
4.4  
(1) As at December 31, 2022, the carrying value of non-current assets included a fair value adjustment of $27.4 million (as at December 31,  
2021 - $14.6 million).  
(2) In the year ended December 31, 2022, the Company’s ownership in Africa Energy changed from 19.8% to 19.7% (year ended December  
31, 2021 - 19.9% to 19.8%).  
PAGE 58  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
B. Eco
(Atlantic) Oil and Gas Ltd. (“Eco”):  
Eco is an oil and gas exploration company with interests in Guyana, Namibia and South Africa.  
On April 6, 2022, Eco completed an equity fundraise. A total of 64,885,496 new Common Shares were placed with, or subscribed  
for, by new and existing institutional investors at a price of £0.30 per Placing Share. The equity fundraise raised gross proceeds of  
approximately $25.5 million for Eco before expenses. The Company subscribed for 10,178,116 common shares for a consideration of  
$4.0 million and following this the Company held 17.3% of the enlarged share capital in Eco.  
On June 27, 2022, Eco signed a farmout agreement in which its wholly owned subsidiary, Azinam Limited, acquired an additional  
6.25% participating interest in Block 3B/4B. The aggregate dollar consideration for the transaction was $10.0 million and was settled  
substantially in Eco shares. Eco received TSX Venture Exchange approval for the transaction on July 6, 2022. Following the approval of  
issuance, the Company held 16.1% of the enlarged share capital in Eco.  
On June 27, 2022, Eco completed an equity fundraise. A total of 33,406,531 new Common Shares were placed with, or subscribed  
for, by new and existing institutional investors at a price of £0.30 per Placing Share. The equity fundraise raised gross proceeds of  
approximately $12.3 million for Eco before expenses. The Company subscribed for 4,864,865 common shares for a consideration of  
$1.8 million and following TSX Venture Exchange approval, the Company held 15.9% of the enlarged share capital in Eco.  
Since June 27, 2022, Eco cancelled a number of shares and issued shares, in which the Company did not participate, and following this  
the Company held 15.0% of the share capital in Eco.  
As at December 31, 2022, the market value of the Company’s investment in Eco is $12.2 million based on a share price of CAD 0.3 (as  
at December 31, 2021 - $11.0 million).  
The following tables summarize Eco’s financial information for the years ended December 31, 2022, (based on preliminary figures) and  
December 31, 2021. The Company is not aware of any material changes to the financial information.  
Balance Sheet  
December 31,  
December 31,  
As at  
2022  
2021  
Cash and cash equivalents included in current assets  
24.6  
6.2  
Other current assets  
4.4  
0.5  
Non-current assets (1)  
75.0  
68.8  
Current liabilities  
(5.7)  
(0.6)  
Non-current liabilities  
-
(2.6)  
Net assets of Eco  
98.3  
72.3  
Percentage ownership (2)  
15.0%  
19.9%  
Proportionate share of Eco’s net assets  
14.7  
14.4  
Statement of Net loss and comprehensive loss from continuing operations  
December 31,  
December 31,  
For the years ended  
2022  
2021  
Net loss and comprehensive loss from continuing operations  
(41.2)  
(2.8)  
Proportionate share of Eco’s net loss  
(6.2)  
(0.5)  
(1) As at December 31, 2022, the carrying value of non-current assets included a fair value adjustment of $36.6 million (as at December 31,  
2021 - $55.9 million).  
(2) In
the year ended December 31, 2022, the Company’s ownership in Eco changed from 19.9% to 15.0% (year ended December 31, 2021 –  
18.4% to 19.9%).  
PAGE 59  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
C. Impact
Oil and Gas Ltd (“Impact”):  
Impact is an oil and gas exploration company with interests in Namibia and South Africa.  
On July 18, 2022, the Company subscribed for 31,936,373 shares in Impact for $19.0 million and following the transaction the Company  
held 30.9% of the enlarged share capital in Impact.  
The following tables summarize Impact’s financial information for the years ended December 31, 2022, (based on preliminary figures)  
and December 31, 2021. The Company is not aware of any material changes to the financial information.  
Balance Sheet  
December 31,  
December 31,  
As at  
2022  
2021  
Cash and cash equivalents included in current assets  
49.2  
40.0  
Other current assets  
0.8  
0.6  
Non-current assets (1)  
199.1  
143.0  
Current liabilities  
(2.7)  
(2.1)  
Non-current liabilities  
(0.4)  
-
Net assets of Impact  
246.0  
181.5  
Percentage ownership (2)  
30.9%  
30.9%  
Proportionate share of Impact’s net assets  
76.0  
56.1  
Statement of Net profit/ (loss) and comprehensive profit/ (loss) from continuing operations  
December 31,  
December 31,  
For the years ended  
2022  
2021  
Net profit and comprehensive loss from continuing operations  
(5.6)  
(4.4)  
Proportionate share of Impact’s loss  
(1.7)  
-
Adjustments to share of loss relating to year ended December 31, 2021  
2.3  
-
Proportionate share of Impact’s income/ (loss) as reported (3)  
0.6  
(1.4)  
(1) As at December 31, 2022, the carrying value of non-current assets included a fair value adjustment of $54.6 million (as at December 31,  
2021 - $35.7 million).  
(2) In
the year ended December 31, 2022, the Company’s ownership in Impact remained 30.9% through the year (year ended December 31,  
2021 – remained 30.9% through the year).  
(3) The
Company has an income for its proportionate share of the result from Impact despite Impact making a loss in the year ended December  
31, 2022, as a result of adjustments relating to 2021 being recorded in 2022.  
7. Intangible
exploration assets:  
December 31,  
December 31,  
Note  
2022  
2021  
Net carrying amount, beginning of the year  
194.3  
190.6  
Intangible exploration expenditures  
A
39.9  
3.7  
Impairment of intangible exploration assets  
B
(170.6)  
-
Net carrying amount, end of the year  
63.6  
194.3  
A. Intangible
exploration expenditures:  
As at December 31, 2022, $63.6 million of expenditures have been capitalized as intangible exploration assets (as at December 31,  
2021 - $194.3 million). These expenditures relate to the Company’s share of exploration and appraisal stage projects which are pending  
the determination of 2P petroleum reserves.  
As at December 31, 2022, the carrying amount of the Company’s intangible exploration assets for its 25% interest in the Project Oil  
Kenya CGU (Block 10BB and 13T) was $58.5 million (as at December 31, 2021 - $189.8 million) following an impairment of the assets.  
The additions to intangible exploration assets during the year include exploration expenditures incurred directly relating to the projects,  
the recognition of a liability for the ongoing court case in Kenya following the decision by the High Court of Kenya (see note 8), a  
provision of $10.0 million related to unresolved Kenya joint venture matters (see note 8) and also include the recognition of a provision  
for costs to decommission and restore the exploration and development sites in Kenya (see note 9).  
PAGE 60  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
As at December 31, 2022, the carrying amount of Block 10BA in Kenya is nil (as at December 31, 2021 - nil).  
As at December 31, 2022, the carrying amount of the Company’s intangible exploration assets for its 20% participating interest in the  
Block 3B/4B Exploration Right, located in South Africa, was $5.1 million (as at December 31, 2021 - $4.5 million). In the year ended  
December 31, 2022, expenditures of $0.6 million were incurred reprocessing the 2D and 3D seismic (year ended December 31, 2021  
- $0.4 million).  
At December 31, 2022, no intangible exploration assets have been transferred to oil and gas interests as commercial reserves have not  
been established and technical feasibility for extraction has not been demonstrated.  
In the year ended December 31, 2022, the Company capitalized $2.1 million of general and administrative expenses related to  
intangible exploration assets (year ended December 31, 2021 - $1.3 million).  
B. Impairment
of intangible exploration assets:  
At December 31, 2022, the Company determined that there was an indicator of impairment for the Project Oil Kenya CGU.The Company  
and its JV partners are actively seeking strategic partners for the project and it is intended that a strategic partner will be secured ahead  
of FID. As there have been continuing delays and uncertainties to the farm out process, the Company considered this an indicator for  
impairment.  
The recoverable amount of a CGU is the higher of fair value less costs to dispose and its value in use.
The Company calculated the fair  
value less costs to dispose using a discounted cash flow method (level 3) to determine the recoverable amount of the project.  
Significant assumptions developed by management used to determine the recoverable amount of the Project Oil Kenya CGU included  
estimates for the quantity of contingent resources, future commodity prices, production forecasts, operating expenses, development  
costs, the likelihood of a successful farm out process, the timing of FID and the discount rate.The estimates for the quantity of contingent  
resources and production forecasts are prepared by the Company’s independent petroleum engineers (management’s experts).  
The Canadian IQRE consensus oil price forecast was used less a quality discount of $3/bbl. The oil price is inherently uncertain as the  
price is often influenced by global events that are unlikely to be foreseen ahead of the event. For purposes of determining the fair value,  
the estimate of discounted cash flows included probability-weighted scenarios and a discount rate of 18% was used, to reflect the time  
value of money based on the risks associated with the Project Oil Kenya CGU that have not otherwise been incorporated in the cash  
flow estimates.  
The results of the impairment test indicated that the carrying value of the Project Oil Kenya CGU exceeded its recoverable amount and  
the Company recognized an impairment loss of $170.6 million.  
At December 31, 2022, a 1% change in the discount rate would result in a change of recoverable amount by $6.0 million. A 5% change  
in the oil prices used would result in a change of recoverable amount by $5.0 million.  
Should the uncertainties around the project be resolved there may be a reversal of previously recognized impairment. However, if the  
uncertainties are not resolved there will be an impairment of $58.5 million.  
C. Reversal
of impairment of intangible exploration assets 2021:  
A reversal of impairment is considered when there is any indication that an impairment loss recognized in prior years for an asset may  
no longer exist or may have decreased.  
At December 31, 2021, the Company determined that due to an increase in the oil price and a reduction of the impact from the global  
pandemic to the wider global market since 2020, that it was appropriate to consider if there had been a reversal of the impairment  
recognized in 2020.
The results of the impairment reversal test indicated that the recoverable amount was not in excess of the carrying  
value.  
PAGE 61  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
8. Accounts
payable and accrued liabilities:  
December 31,  
December 31,  
2022  
2021  
Provision for unresolved joint venture matters  
10.0  
-
Joint venture payables, tax settlement and administrative accruals  
27.2  
3.7  
Balance, end of the year  
37.2  
3.7  
A provision of $10.0 million related to unresolved Kenya joint venture matters has been recognized in intangible exploration assets.  
Joint venture payables, tax settlement and administrative accruals includes a liability for the ongoing court case in Kenya following the  
decision by the High Court of Kenya.  
The Company’s Kenyan Branch, of its wholly owned subsidiary, Africa Oil Kenya B.V. (“AOKBV”), has been assessed for corporate  
income tax and value added tax by the Kenya Revenue Authority (“KRA”) relating to farmout transactions completed during the period  
2012 to 2017.  
On April 8, 2020, Africa Oil announced that Kenya Tax Appeals Tribunal (“TAT”) ruled in favour of AOKBV with regards to the CIT  
assessments and in favour of KRA with regards to the VAT assessments. Subsequently, AOKBV filed an appeal with the High Court of  
Kenya to challenge the VAT decision and KRA filed an appeal in relation to the CIT decision.  
On November 30, 2022, the High Court of Kenya announced its decisions on AOKBV and KRA’s Tax Appeal. AOKBV’s appeal with  
regard to the VAT assessment was partly successful and the High Court concluded that AOKBV owes VAT in an amount of Kenyan  
Shillings 2,293,334,065 (approximately US$ 18.7 million). The KRA’s appeal with regard to the CIT decision was also partly successful  
and the High Court concluded that the KRA was correct to disallow certain costs claimed by AOKBV; however, it is not expected to have  
a material cashflow impact to the Company.  
AOKBV maintains its position that the VAT assessment is without merit and has duly filed a Notice of Appeal with Kenya’s Court of  
Appeal to challenge the position. The KRA has filed a Notice of Appeal regarding the CIT assessment. There is uncertainty as to the  
final outcome of the ongoing court case and therefore, the final outcome is indeterminable at this time. Although AOKBV is taking  
legal advice on the options available to it in view of this decision, including the option to appeal, a liability has been recognised as at  
December 31, 2022, as a result of the High Court ruling.  
9. Provision
for site restoration:  
December 31,  
December 31,  
2022  
2021  
Balance, beginning of the year  
-
-
Additions in the year  
5.3  
-
Balance, end of the year  
5.3  
-
The fair value of the provision for site restoration was based on the estimated future cash flows to decommission the exploration and  
development properties at the end of their useful life.The discount rate used to determine the net present value of the decommissioning  
obligation was 3.5% based on a risk-free rate with a similar maturity to that of the timing of the expected cash flows and a long term  
inflation rate of 2%.  
The undiscounted costs at December 31, 2022, were estimated to be $7.7 million, net to the Company, and include the costs of  
physical well abandonment and to remove equipment from local bases. The costs are estimated to be incurred in approximately 25  
years. The total provision is $5.3 million.  
10. Debt:  
December 31,  
December 31,  
2022  
2021  
Balance, beginning of the year  
-
141.0  
Repayment of Term Loan  
-
(141.0)  
Drawdown of Corporate Facility  
-
98.0  
Repayment of Corporate Facility  
-
(98.0)  
Balance, end of the year  
-
-
PAGE 62  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
In the second quarter of 2021, the Company agreed a new Corporate Facility to refinance its Prime acquisition facility (“Term Loan”) for  
an amount up to $160.0 million with a three-year term. On July 30, 2021, $98.0 million was drawn down under the Corporate Facility  
to repay the Term Loan in full. By November 2021 the facility was repaid in full with the proceeds from Prime dividends. The Corporate  
Facility carries interest of 1 month-Libor plus a margin of 6.5% in the first year, 7.0% in the second year and 7.5% in the third year.  
On January 28, 2022, the Company agreed a number of amendments to the Corporate Facility with the existing lenders. The available  
amount increased from $62.0 million to $100.0 million, and the availability period was extended to December 31, 2022, from May 13,  
2022. The principal amounts, if drawn, may not exceed $80.0 million by September 30, 2023, and $50.0 million by February 29, 2024.  
The maturity date, the loan purpose and interest margins were unchanged. On December 7, 2022, the Company agreed to extend the  
availability period of the Corporate Facility with existing lenders to May 31, 2023.  
On October 20, 2022, the Company agreed amendments which will become effective on licence renewal being received on OML 130  
within Prime. The Corporate Facility amount will be increased from $100.0 million to $200.0 million and can be drawn until October 20,  
2023. The maturity date has been extended to October 20, 2025.  
Any loan repayments are calculated to be protective of the Company’s liquidity position. Prior to maturity, repayments under the loan  
are made in the month a dividend is received from Prime. The Company’s loan repayments reduce commensurately with any reduction  
in dividends from Prime. If drawn, the loan principal would be repaid by the lesser of 100% of the dividends received from Prime, and of  
an amount that ensures the Company hold a minimum projected consolidated cash balance in the six months following the repayment.  
The Company provided security in respect of the Corporate Facility mainly in the form of share pledges, over the shares of Petrovida  
(which holds 50% of Prime), Africa Energy, Eco and Impact owned by the Company and a charge over the bank account into which  
the Prime dividends are paid. The security over the shares in Africa Energy, Eco and Impact were released in the amendment to the  
Corporate Facility on January 28, 2022.  
The Corporate Facility is subject to financial and liquidity covenants. The Company has been in compliance with the covenants in the  
year ended December 31, 2022.  
11. Share
capital:  
A. The Company is authorized to issue an unlimited number of common shares with no par value.  
B. Issued:  
December 31,  
December 31,  
2022  
2021  
Shares  
Amount  
Shares  
Amount  
Balance, beginning of the year  
474,655,355  
1,309.1  
471,960,472  
1,306.5  
Settlement of Performance Share Units  
1,170,149  
1.9  
515,445  
0.5  
Settlement of Restricted Share Units  
678,224  
1.2  
882,104  
0.9  
Exercise of Share Options  
3,724,000  
3.4  
1,297,334  
1.2  
Return and cancellation of shares  
(11,858)  
-
-
-
Cancellation of shares repurchased  
(17,425,190)  
(47.9)  
-
-
Balance, end of the year  
462,790,680  
1,267.7  
474,655,355  
1,309.1  
The Company launched a Normal Course Issuer Bid (share buyback) program on September 27, 2022. Since that date to December  
31, 2022, a total of 17,425,190 Africa Oil common shares have been repurchased and cancelled. The balance of share capital has been  
reduced by determining the average per-share amounts in the share capital account, before cancellation of shares repurchased, and  
applying this to the numbers of shares cancelled. The difference between the reduction in share capital and the amount paid for shares  
repurchased has been added to the balance of contributed surplus.  
In the year ended December 31, 2022, the Board of Directors approved an initial aggregate annual dividend of $0.05 per share which  
was declared and paid semi-annually with $11.9 million ($0.025 per share) being paid in both March and September 2022.  
12. Commitments
and contingencies:  
A. Investment
in Prime:  
Under the Prime Sale and Purchase Agreement completed on January 14, 2020, a deferred payment of $118.0 million, subject to  
adjustment, may be due to the seller contingent upon the timing and final OML 127 tract participation in the Agbami field. The  
signing of the Securitization Agreement by Prime has led to the Company reassessing its view of the likelihood of making a contingent  
consideration payment to the seller. The signing of the Securitization Agreement by Prime does not constitute a redetermination of the  
tract participation and therefore does not trigger the payment of a contingent consideration under the Sale and Purchase Agreement  
but, at the Company’s discretion, could trigger discussions with the seller. The outcome of this process is uncertain. In 2021, the  
Company recorded $32.0 million as contingent consideration and increased the Company’s investment in Prime.  
PAGE 63  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
B. Kenya
license commitments:  
Under the terms of the Block 10BA PSC, the Company received approval from the Ministry of Petroleum and Mining for the Republic of  
Kenya for an extension to the second additional exploration period to April 26, 2023, allowing time for the joint venture to include and  
align the Block 10BA work program with the proposed FDP for Blocks 10BB and 13T. During the second additional exploration period,  
the Company and its partners are obligated to complete geological and geophysical operations, including either 500 km2 of 2D or  
45 km2 of 3D seismic. Additionally, the Company and its partners are obligated to drill one exploration well. The total minimum gross  
expenditure obligation for the second additional exploration period is $19.0 million. The JV partners have not provided any letters of  
credit or guarantees for this commitment. The Company has presented a plan for exploration and appraisal in Block 10BA in the FDP.  
This drilling plan was formally submitted in December 2021. At December 31, 2022, the Company’s working interest in Block 10BA  
was 25%.  
C. South
Africa license commitments:  
The application to extend the Block 3B/4B license and to move into the first extension period of 2 years was approved on October 27,  
2022. The work commitment for this extension period includes the completion of 2,020 square kilometres of 3D seismic reprocessing  
and integration of well and seismic data. At December 31, 2022, the Company’s WI in Block 3B/4B was 20%.  
13. Finance
income and expense:  
Finance income and expense for the years ended December 31, 2022, and December 31, 2021, is comprised of the following:  
December 31,  
December 31,  
For the years ended  
2022  
2021  
Finance income  
2.4  
0.1  
Finance expense  
(3.5)  
(18.3)  
Interest income includes interest earned on cash in bank accounts and also interest earned on short term deposits.  
Interest expense and bank charges includes interest incurred on the Term Loan and the Corporate Facility (see note 10) and the  
commitment and arrangement fees associated with these financing arrangements.  
14. Net
(loss)/ income per share:  
December 31,  
December 31,  
For the years ended  
2022  
2021  
Weighted Average  
Weighted Average  
Number of  
Per share  
Net  
Number of  
Per share  
Net loss  
shares  
amounts  
income  
shares  
amounts  
Basic (loss)/ income per share  
Net (loss)/ income attributable  
(60.3)  
474,366,637  
(0.13)  
190.7  
473,332,153  
0.40  
to common shareholders  
Effect of dilutive securities  
-
-
-
-
4,029,133  
-
Dilutive (loss)/ income per share  
(60.3)  
474,366,637  
(0.13)  
190.7  
477,361,286  
0.40  
In the year ended December 31, 2022, the Company made a loss and therefore all potential dilutive shares are considered anti-  
dilutive. In the year ended December 31, 2022, 1,591,613 options, 2,066,248 RSU’s and 8,553,628 PSU’s were anti-dilutive and were  
not included in the calculation of dilutive loss per share (year ended December 31, 2021 - 22,616 options were anti-dilutive). PSU’s are  
awarded a performance multiple ranging from nil to 200% (see note 15) which leads to an increase in the anti-dilutive potential of these  
instruments. The Company used an average market price of CAD $2.48 per share to calculate the anti-dilutive effect of share purchase  
options (year ended December 31, 2021 - CAD $1.47 per share was used to calculate the dilutive effect).  
PAGE 64  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
15. Share-based
compensation:  
In the year ended December 31, 2022, the Company recognized a total of $9.5 million in share-based compensation expense relating  
to the Long-Term Incentive Plan (“LTIP”) and Stock Option Plan (year ended December 31, 2021 – $6.3 million).  
A. Share
purchase options:  
At the 2019 Annual General Meeting, held on April 18, 2019, the Company’s shareholders approved the terms of the stock option plan  
(the “Plan”). The Plan provides that an aggregate number of common shares which may be reserved for issuance as incentive share  
purchase options shall not exceed 3.5% of the common shares outstanding, and option exercise prices will reflect current trading  
values of the Company’s shares. The term of any option granted under the Plan will be fixed by the Board of Directors and may not  
exceed five years from the date of grant. Vesting periods are determined by the Board of Directors and no optionee shall be entitled  
to a grant of more than 5% of the Company’s outstanding issued shares. The Board no longer grants share purchase options under the  
Plan and instead only awards PSUs to executives and staff.  
The Company’s outstanding share purchase options are as follows:  
December 31,  
December 31,  
2022  
2021  
Weighted average  
Weighted average  
Number of  
Exercise price  
Number of  
Exercise price  
options  
(CAD$)  
options  
(CAD$)  
6,877,950  
1.18  
Outstanding, beginning of the year  
9,618,000  
1.31  
-
-
Granted  
22,616  
1.61  
-
-
Expired  
(1,233,000)  
2.12  
(153,334)  
1.21  
Forfeited  
(232,332)  
1.49  
(3,724,000)  
1.19  
Exercised  
(1,297,334)  
1.17  
Balance, end of the year  
3,000,616  
1.16  
6,877,950  
1.18  
In the year ended December 31, 2022, no share purchase options expired (year ended December 31, 2021 – 1,233,000). In the year  
ended December 31, 2022, 3,724,000 million share purchase options were exercised (year ended December 31, 2021 – 1,297,334  
million).  
The following table summarizes information regarding the Company’s share purchase options outstanding and exercisable at  
December 31, 2022:  
Weighted Average  
Weighted average remaining  
Exercise price (CAD$/share)  
Number outstanding  
Number exercisable  
contractual life in years  
1.06  
456,000  
456,000  
0.96  
1.06  
50,000  
50,000  
1.02  
1.13  
70,000  
70,000  
1.63  
1.22  
155,667  
155,667  
1.88  
1.15  
1,079,333  
1,079,333  
1.95  
1.21  
1,167,000  
1,167,000  
2.95  
1.61  
22,616  
15,077  
3.63  
3,000,616  
2,993,077  
All options granted vest over a two-year period, of which one-third vest immediately, and expire five years after the grant date. In  
the year ended December 31, 2022, the Company recognized $0.1 million as a share-based compensation expense (year ended  
December 31, 2021 - $0.4 million), related to share purchase options.  
PAGE 65  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
B. Performance
share units (“PSUs”):  
On April 19, 2016, the shareholders of the Company approved a new LTIP. Under the terms of the LTIP, eligible plan participants may  
be granted PSUs and RSUs. The LTIP provides that an aggregate number of common shares which may be reserved for issuance shall  
not exceed 4% of the issued and outstanding common shares of the Company. PSUs are notional share instruments which track the  
value of the common shares and are subject to non-market performance conditions related to key strategic, financial and operational  
milestones. PSUs cliff vest three years from the date of grant, at which time the Board of Directors will assign a performance multiple  
ranging from nil to 200% to determine the ultimate vested number of PSUs. PSUs are awarded to executives and from 2022 will be  
awarded to staff, replacing share options. They may be settled in shares issued from treasury or cash, at the discretion of the Board of  
Directors.  
The Company’s PSUs outstanding are as follows:  
December 31,  
December 31,  
2022  
2021  
Number of PSUs  
Number of PSUs  
Outstanding, beginning of the year  
7,795,512  
7,615,412  
2,165,986  
2,331,600  
Granted  
(423,945)  
(1,275,840)  
Cancelled  
Vested  
(1,895,667)  
(875,660)  
Balance, end of the year  
7,641,886  
7,795,512  
In March 2022, 1,788,356 PSUs vested in which 671,863 PSUs were settled for a cash payment of $1.2 million and the remaining were  
settled via the issuance of common shares of the Company. In November 2022, 107,311 PSUs vested and were settled half in shares  
and the remaining for a cash payment of $0.1 million.  
The Company accounts for PSUs as share-based awards whereby the estimated fair value of the grant is expensed evenly throughout the  
remaining vesting period. In the year ended December 31, 2022, the Company recognized $7.7 million in share-based compensation  
relating to the PSUs (year ended December 31, 2021 - $3.9 million) with the increase mainly caused by a higher share price. These  
liabilities are revalued quarterly.  
C. Restricted
share units (“RSUs”):  
RSUs granted to Non-Executive Directors cliff vest three years from the date of grant. RSUs granted to all other eligible plan participants  
vest over three years (1/3 on the first, second and third anniversary of the grant). The estimated fair value of RSUs are expensed evenly  
throughout the remaining vesting period. RSUs are no longer awarded to executives, and only PSU’s are awarded. RSUs may be settled  
in shares issued from treasury or cash, at the discretion of the Board of Directors.  
The Company’s RSUs outstanding are as follows:  
December 31,  
December 31,  
2022  
2021  
Number of RSUs  
Number of RSUs  
Outstanding, beginning of the year  
2,668,335  
3,189,469  
Granted  
410,691  
605,000  
Cancelled  
(108,100)  
-
Vested  
(904,678)  
(1,126,134)  
Balance, end of the year  
2,066,248  
2,668,335  
In 2022, 410,691 RSUs were granted to Non-Executive Directors only (year ended December 31, 2021 – 605,000). RSUs were not  
granted to other plan participants in 2022 to align with the Company’s revised compensation strategy of granting PSUs to executive  
management.  
In March 2022, 893,133 RSUs vested with 220,682 being settled for a cash payment of $0.4 million and the remaining were settled  
via the issuance of common shares of the Company. In November 2022, 11,545 RSUs vested and were settled half in shares and the  
remaining in cash.  
The Company accounts for RSUs as share-based awards whereby the estimated fair value of the grant is expensed evenly throughout the  
remaining vesting period. In the year ended December 31, 2022, the Company recognized $1.7 million in share-based compensation  
relating to the RSUs (year ended December 31, 2021 - $2.0 million). These liabilities are revalued quarterly.  
PAGE 66  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
16. Capital
management:  
The Company’s objective when managing capital structure is to maintain balance sheet strength in order to ensure the Company’s  
strategic exploration, appraisal and business development objectives are met while providing an appropriate return to shareholders  
relative to the risk of the Company’s underlying assets.  
The Company manages its capital structure and makes adjustments to it based on changes in economic conditions and the risk  
characteristics of the underlying assets. In order to maintain or adjust the capital structure, the Company may issue additional shares,  
issue debt, execute working interest farm-out arrangements and revise its capital expenditures program. In addition, the Company  
manages its cash and cash equivalents balances based on forecasted capital outlays and foreign exchange risks in order to ensure that  
the risk of negative foreign exchange effects are minimized while ensuring that interest yields on account balances are appropriate.  
The Company considers its capital structure to include shareholder’s equity, debt and working capital. The Company does not have  
externally imposed capital requirements.  
17. Related
party transactions:  
A. Transactions
with Africa Energy:  
As at December 31, 2022, the Company’s ownership interest in Africa Energy is approximately 19.7%.  
Services Agreements:  
December 31,  
December 31,  
For the years ended  
Service provider  
Service provided  
2022  
2021  
General Management and
AOC to  
Administrative services provided  
-
0.1  
Service Agreement  
Africa Energy  
to Africa Energy.  
Technical and administrative  
General Technical and  
Africa Energy to  
services relating to its operating  
Administrative Service  
0.4  
0.4  
AOSAC  
interest in Block 3B/4B,  
Agreement  
South Africa.  
In December 2022, the Company signed a Promissory note with Africa Energy, alongside other parties, with a total value of $5.0 million,  
in which the Company agreed to provide $2.0 million. This amount was drawn in December 2022. The note carries interest of 10% from  
drawdown until October 31, 2023, at which time the annual interest rate for any outstanding amount increases to 15%, retrospectively.  
The maturity date of the loan is January 31, 2024.  
B. Transactions
with Eco:  
On June 28, 2021, the Company subscribed for 5,945,913 new common shares at a price of CAD$0.41 per new common share totaling  
$2.0 million and was granted the same number of warrants to acquire common shares at the same price over a two-year period.  
On April 6, 2022, the Company subscribed for 10,178,116 common shares for a consideration of $4.0 million and following this the  
Company held 17.3% of the enlarged share capital in Eco (see note 6).  
On June 27, 2022, the Company subscribed for 4,864,865 common shares for a consideration of $1.8 million and the Company held  
15.9% of the enlarged share capital in Eco (see note 6).  
As at December 31, 2022, the Company’s ownership interest in Eco is approximately 15.0%.  
C. Transactions
with Impact:  
On July 18, 2022, the Company subscribed for 31,936,373 shares in Impact for $19.0 million and following the transaction the Company  
held 30.9% of the enlarged share capital in Impact (see note 6).  
As at December 31, 2022, the Company’s ownership interest in Impact is approximately 30.9%.  
D. Remuneration
of Directors and Senior Management:  
Remuneration of Non-Executive Directors and Senior Management includes all amounts earned and awarded to the Company’s  
Board of Directors and Senior Management. Senior Management includes the Company’s President and Chief Executive Officer, Chief  
Financial Officer, Chief Operating Officer and Vice President of Exploration.  
Directors’ fees include Board and Committee Chair retainers. Management’s short-term wages and benefits include salary, benefits,  
bonuses and any other cash-based compensation earned or awarded during the year. Share-based compensation includes expenses  
related to the Company’s share purchase option plan as well as the Long-Term Incentive Plan.  
December 31,  
December 31,  
For the years ended  
2022  
2021  
Non-Executive Directors' fees  
0.4  
0.4  
Non-Executive Directors' share-based compensation  
1.0  
0.9  
Managements' short-term wages and benefits  
3.8  
3.1  
Managements' share-based compensation  
4.8  
3.4  
10.0  
7.8  
PAGE 67  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
18. Subsidiaries:  
The Company has the following material wholly owned subsidiaries; Africa Oil Holdings B.V. (Netherlands), Africa Oil Turkana B.V.  
(Netherlands), Africa Oil Kenya B.V. (Netherlands), PetroVida Holding B.V. (Netherlands), Africa Oil Gamma B.V (Netherlands), Africa  
Oil Turkana Ltd. (Kenya), Centric Energy (Kenya) Ltd. (Kenya), Africa Oil UK Limited (United Kingdom) and Africa Oil SA Corp. (British  
Columbia).  
19. Financial
risk management:  
The Company’s activities expose it to a variety of financial risks that arise as a result of its exploration, appraisal and financing activities  
such as:  
credit risk;  
liquidity risk; and  
market risk.  
This note presents information about the Company’s exposure to each of the above risks, the Company’s objectives, policies and  
processes for measuring and managing risk, and the Company’s management of capital. Further quantitative disclosures are included  
throughout these consolidated financial statements.  
A. Credit
risk:  
Credit risk is the risk of loss if counterparties do not fulfill their contractual obligations. The majority of our credit exposure relates to  
amounts due from our joint venture partners and a loan with Africa Energy.
The risk of our joint venture partners defaulting on their  
obligations per their respective joint operating and farmout agreements is mitigated as there are contractual provisions allowing the  
Company to default joint venture partners who are non-performing and reacquire any previous farmed out working interests. The  
maximum exposure for the Company is equal to the sum of its cash and accounts receivable.
As at December 31, 2022, the Company  
held $0.9 million (as at December 31, 2021 - $0.9 million) of cash in financial institutions outside of Canada and the UK. The Company  
also held $30.2 million (as at December 31, 2022 - nil) in short-term deposits in countries outside of Canada and the UK with lending  
banks in the Corporate Facility.  
B. Liquidity
risk:  
Liquidity risk is the risk that the Company will not be able to meet its financial obligations as they become due. Liquidity describes a  
company’s ability to access cash. Companies operating in the upstream oil and gas industry, during the exploration and development  
phase, require sufficient cash in order to fulfill their work commitments in accordance with contractual obligations, deliver stated  
shareholder returns, and to be able to potentially acquire strategic oil and gas assets.  
The Company will potentially issue equity and debt and enter into farmout agreements with joint venture partners to ensure the  
Company has sufficient available funds to meet current and foreseeable financial requirements. The Company actively monitors its  
liquidity to ensure that its cash flows and working capital are adequate to support these financial obligations and the Company’s capital  
programs.  
The Company’s primary source of cash flow relates to dividends received from Prime.Asignificant reduction in or infrequent distributions,  
could have an adverse effect on the Company’s ability to meet its commitments. The Company has senior members sitting on Prime’s  
Supervisory Board and Audit Committee, monitoring cash forecasts and setting financial and risk management policies to manage  
Prime’s dividend forecasts.  
The Company has $100.0 million of available debt facility which improve the Company’s access to liquidity to fund operations and  
acquisitions as required. Any loan repayments are calculated to be protective of the Company’s liquidity position and if drawn, the  
Corporate Facility would be repaid from the proceeds of dividends received from Prime, while ensuring the Company preserves a  
sufficient minimum cash balance to conduct operations. The Company agreed amendments which will become effective on licence  
renewal being received on OML 130 within Prime. The Corporate Facility amount will be increased from $100.0 million to $200.0 million  
and can be drawn until October 20, 2023. The maturity date has been extended to October 20, 2025 (see note 10).  
The Company will also adjust the pace of its exploration and appraisal activities to manage its liquidity position. The existing cash  
balance, the undrawn amount of the Corporate Facility and expected dividends from its Investment in Prime, are sufficient to fund the  
Company’s obligations as they become due.  
The Company has no maturities of its material contractual financial liabilities in excess of six months as at December 31, 2022 (As at  
December 31, 2021 – no maturities of its material contractual liabilities in excess of six months).  
PAGE 68  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
C. Market
risk:  
Market risk is the risk that changes in market prices, such as foreign exchange rates, interest rates, commodity prices and share prices,  
will affect the Company’s income or the value of the financial instruments.  
i. Foreign
currency exchange rate risk:  
The Company is exposed to changes in foreign exchange rates as expenses in international subsidiaries, oil and gas expenditures, or  
financial instruments may fluctuate due to changes in rates. The Company’s exposure to foreign currency exchange risk is mitigated by  
the fact that the Company sources the majority of its capital projects and expenditures in US dollars. The Company has not entered into  
any instruments to manage foreign exchange risk.  
ii. Interest
rate risk:  
The Corporate Facility has a variable interest rate, that is referenced to LIBOR and will expose the Company to interest rate risk over  
the term of the loan. The Financial Conduct Authority of the United Kingdom has announced that one month USD LIBOR (which the  
Corporate Facility applies) will cease to be provided by any administrator or no longer be representative after June 30, 2023. The  
amendment to the Corporate Facility signed on October 20, 2022, includes SOFR as the replacement benchmark from the effective  
date of the amendment.  
iii. Commodity
price risk:  
The Company has an equity holding in Prime (see note 5), which has three producing fields within OML127 and OML 130, both with  
significant levels of production.
A change in commodity prices may affect the dividends received from this investment. Prime benefits  
from a robust oil price forward sales program and the forward sales policy requires forward selling between 50% and 70% of its forecast  
liftings on a rolling 12-month basis. These contracts are with counterparties including oil supermajors. The counterparties are part of  
groups with investment grade credit ratings.  
iv. Share
price risk:  
The Company has shareholdings in Africa Energy and Eco, which are entities listed on Canadian and European Stock Exchanges. The  
share price of these investments can be volatile and a change in share price may affect the amount that the Company can realize for  
these investments.  
20. Financial
instruments:  
As at December 31, 2022, and December 31, 2021, assets and liabilities that are measured at fair value are classified into levels  
reflecting the method used to make the measurements. Fair values of assets and liabilities included in Level 1 are determined by  
reference to quoted prices in active markets for identical assets and liabilities. Assets and liabilities in Level 2 include valuations using  
inputs other than quoted prices for which all significant inputs are observable, either directly or indirectly. Level 3 valuations are based  
on inputs that are unobservable and significant to the overall fair value measurement.  
The Company’s cash and cash equivalents, accounts receivable, loan to associate company, accounts payable and accrued liabilities,  
and long-term debt are assessed on the fair value hierarchy described above. The fair value of cash and cash equivalents, accounts  
receivable,accounts payable and accrued liabilities approximate their carrying value due to the short-term maturity of these instruments.  
Assessment of the significance of a particular input to the fair value measurement requires judgement and may affect the placement  
within the fair value hierarchy level. There were no transfers between levels in the fair value hierarchy in the year.  
21. Income
taxes:  
The tax rate consists of the combined federal and provincial statutory tax rates for the Company for the years ended December 31,  
2022, and December 31, 2021. Substantially all of the differences between actual income tax expense of nil and the expected Canadian  
federal and provincial statutory corporate income tax expense/ (recovery) related to losses not recognized.  
The following table reconciles the expected tax (recovery)/ expense calculated at the Canadian statutory rate with the actual tax recovery.  
December 31,  
December 31,  
For the years ended  
2022  
2021  
Net (loss)/ profit and comprehensive (loss)/ profit  
(60.3)  
190.7  
Combined federal and provincial statutory income tax rate  
28.0%  
27.0%  
Expected (recovery)/ expense  
(16.9)  
51.5  
Foreign rate differences  
(0.5)  
(1.0)  
Permanent differences  
2.5  
0.3  
Share-based compensation  
0.7  
0.5  
Equity earnings  
(37.5)  
(63.0)  
Non-taxable expense items  
47.8  
-
Unrecognized tax losses  
3.9  
11.7  
Tax recovery  
-
-
PAGE 69  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED  
The Company has the following unrecognized deductible temporary differences:  
December 31,  
December 31,  
As at  
2022  
2021  
Unrecognized deductible temporary differences  
Capital assets  
0.8  
(0.6)  
Unrealized loss on equity investments  
34.0  
25.8  
Capital losses carried forward  
12.9  
12.9  
Share-based compensation  
12.6  
7.9  
Non-capital and operating losses carried forward  
434.6  
489.3  
Charitable donations  
1.5  
2.8  
496.4  
538.1  
The Company has estimated non-capital losses carried forward of $84.0 million in Canada which expire from 2028 through 2039. The  
Company recognized deferred tax assets and liabilities associated with its investments in subsidiaries and associates to the extent  
that the temporary differences would reverse in the foreseeable future and have been netted under IFRS as they relate to the same  
jurisdiction. The Company has not recognized any withholding or other taxes on unremitted earnings as the Company expects to  
repatriate these earnings free of tax.  
No deferred tax asset or liability is recognized at December 31, 2022.  
22. Supplementary
information:  
The following table reconciles the changes in non-cash working capital as disclosed in the consolidated statement of cash flows:  
December 31,  
December 31,  
For the years ended  
2022  
2021  
Relating to:  
Operating activities  
1.2  
0.2  
Investing activities  
0.3  
(5.7)  
Changes in non-cash working capital  
1.5  
(5.5)  
23. Subsequent
events:  
From January 1, 2023, to February 24, 2023, a total of 2.7 million Africa Oil common shares have been repurchased under the Normal  
Course Issuer Bid, for an amount of approximately $4.9 million and 2.7 million shares have been cancelled.  
On February 20, 2023, the Company announced it had signed two PSCs with the Republic of Equatorial Guinea for offshore Blocks EG-  
18 and EG-31.
These PSCs are subject to ratification by the country’s government. Africa Oil will hold eighty per cent (80%) operated  
interests in each block with the balance to be held by GEPetrol, the national oil company of Equatorial Guinea. GEPetrol has the option  
of acquiring an additional fifteen percent (15%) participating interest in each block. Both blocks are covered by 3D seismic data and the  
total minimum work commitment for both blocks in the initial exploration periods is a combined total of USD 7 million, with no drilling  
commitment.  
On February 27, 2023, the Company announced it will pay a semi-annual dividend of $0.025 per share (approximately $11.6 million)  
with the payment to be made at the end of March 2023.  
PAGE 70  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
GLOSSARY  
means Africa Energy Corp. an international oil and gas exploration company that holds a 27.5%  
participating interest in the offshore Exploration Right for Block 2B in South Africa, an effective  
14.6% participating interest in offshore PEL 37, and an effective 9.9% participating interest in the  
Exploration Right for Block 11B/12B offshore South Africa.  
“Africa Energy”  
“Africa Oil, “AOC”, or  
the “Company”  
means Africa Oil Corp.  
A
“AGC”  
means Senegal Guinea Bissau Joint Development Zone.  
means Azinam Group Ltd.  
“AGL”  
means all laws and regulations issued by authorities that have appropriate jurisdiction over the  
Company.  
“Applicable law”  
“Azinam”  
means Azinam Ltd.  
“boepd”  
means barrels of oil equivalent per day.  
B
means Cash Generating Unit. A Cash Generating Unit is defined as assets that are grouped  
together into the smallest group of assets that generates cash inflows from continuing use that  
are largely independent of the cash inflows of other assets or groups of assets.  
“CGU”  
“Chevron”  
“CIT”  
means Chevron Corp.  
means Corporate Income Tax.  
“Concessions, PSC”  
means concessions, production sharing contracts and other similar agreements entered into  
C
or “Production Sharing with a host government providing for petroleum operations in a defined area and the division of  
Contract”  
petroleum production from the petroleum operations.  
means a $150.0 million facility dated May 13, 2021, with a three-year term, amended to a $160.0  
million facility on July 16, 2021, and subsequently amended on January 28, 2022, to increase the  
available amount under the facility to $100.0 million from the then unutilized amount of $62.0  
million, and an extension of the availability period to December 31, 2022, from May 13, 2022.  
On December 7, 2022, the Company agreed to extend the availability period of the Corporate  
Facility with existing lenders to May 31, 2023.  
“Corporate Facility”  
“DD&A”  
“E&A”  
means Depreciation, Depletion and Amortization.  
D
E
means Exploration and Appraisal.  
“EBITDA”  
means Earnings Before Interest, Taxes, Depreciation & Impairment, and Amortization.  
means Earnings Before Interest, Taxes, Depreciation & Impairment, Amortization and Exploration  
Expenses.  
“EBITDAX”  
“Eco”  
means Eco (Atlantic) Oil & Gas Ltd. An international oil and gas exploration company that holds  
working interests in four exploration blocks offshore Namibia and one exploration block offshore  
Guyana.  
“Entitlement  
production”  
means production that is calculated using the economic interest methodology and includes cost  
recovery oil, tax oil and profit oil.  
“Equinor”  
“ESG”  
“ESIA”  
“FCF”  
means Equinor ASA.  
means Environmental, Social and Governance.  
means Environmental and Social Impact Assessment.  
means Free Cash Flow.  
“FDP”  
means Field Development Plan.  
F
“FID”  
means Final Investment Decision.  
“FPSO”  
“GoK”  
“IFRS”  
means Floating Production Storage and Offloading.  
means Government of Kenya.  
G
I
means International Financial Reporting Standards.  
means Impact Oil and Gas Ltd, a privately owned exploration company with a strategic focus on  
large scale, mid to deep water plays of sufficient materiality to be of interest to major companies.  
Impact has an asset base across the offshore margins of Southern and West Africa.  
“Impact”  
PAGE 71  
 
Report to Shareholders | December 31, 2022  
Africa Oil Corp.  
JHI”  
means JHI Associates Inc.  
means Joint Venture.  
J
JV”  
“KRA”  
means Kenya Revenue Authority.  
means Long Term Incentive Plan.  
K
LTIP”  
L
“Lokichar Development means the development of the oil resources contained in the South Lokichar Basin (Blocks 10BB  
Project”  
and 13T (Kenya)), for export via a pipeline to the coast of Kenya.  
“M&A”  
means mergers and acquisitions.  
“MD&A”  
“MMbbl”  
“MMBoe”  
means Management’s Discussion and Analysis.  
means one million barrels.  
M
means millions of barrels of oil equivalent.  
means National Instrument 51-101 — Standards of Disclosure for Oil and Gas Activities of the  
Canadian Securities Administrators and the companion policies and forms thereto, as amended  
from time to time.  
“NI 51-101”  
“NI 52-109”  
N
O
means National Instrument 52-109 – Certification of Disclosure in Issuers’ Annual and Interim  
Filings and the companion policies and forms thereto, as amended from time to time.  
“NUPRC”  
“OML”  
means Nigeria Upstream Petroleum Regulatory Commission.  
means Oil Mining Lease.  
“Petrovida”  
“PIA”  
means Petrovida Holding B.V.  
means Petroleum Industry Act.  
“PPT”  
means Profit Petroleum Tax.  
“Prime” or “Prime Oil & means Prime Oil & Gas Coöperatief U.A., previously known as Prime Oil & Gas B.V., a company  
Gas Coöperatief U.A.”  
that holds interests in deepwater Nigeria production and development assets.  
P
“Project Oil Kenya”  
means the Company’s Kenya development project incorporating Blocks 10BB and 13T.  
“PSA”  
means Petroleum Sharing Agreement.  
means Performance Share Unit.  
means Pre-Export Finance Facility.  
means Reserves Based Lending.  
means Restricted Share Unit.  
“PSU”  
“PXF Facility”  
“RBL”  
R
S
“RSU”  
“spud” or “spudded”  
“TAT”  
means the initial drilling for an oil well.  
means Tax Appeals Tribunal.  
means a $250.0 million facility dated January 11, 2020, provided by BTG Pactual S.A for the  
purpose of funding the acquisition of 50% of Petrobras Oil & Gas B.V. (now Prime Oil & Gas  
Coöperatief U.A.).  
Term Loan”  
T
TotalEnergies”  
“TSX”  
means TotalEnergies SE and subsidiaries.  
means Toronto Stock Exchange.  
means Tullow Oil plc.  
Tullow”  
“US”  
means United States.  
U
V
“VAT”  
means Value-added tax.  
“WI”  
means working interest.  
W
“WI production”  
means production based on the percentage of working interest owned.  
PAGE 72  
 
AFRICAOILCORP.COM