Zephyr Energy Regulatory News (ZPHR)

Prior to publication, the information contained within this announcement was deemed by the Company to constitute inside information as stipulated under the UK Market Abuse Regulation. With the publication of this announcement, this information is now considered to be in the public domain.

23 June 2022

Zephyr Energy plc

("Zephyr" or the "Company")

Full Year Results for the year ended 31 December 2021

Notice of AGM

Zephyr Energy plc (AIM: ZPHR) (OTCQB: ZPHRF), the Rocky Mountain oil and gas company focused on responsible resource development from carbon-neutral operations, is pleased to announce its audited results for the year ended 31 December 2021.

Highlights

A transformational period in which Zephyr evolved from a single project exploration company into a self-sustaining, cash generating, oil producing group with a balanced portfolio of operated and non-operated assets in two established U.S. oil producing basins.

 Paradox Project, Utah, U.S. (operated asset)

· First flowing hydrocarbons from the Company's State 16-2 LN-CC well, a historical and operational milestone after many years of investment in the project.

· Sproule completed Competent Persons Report ("CPR") which highlighted the scale and resource potential of the project:

o  2P Reserves: First Paradox Basin Proved Reserves of 2.1 million barrels of oil equivalent ("boe")

o  2C Resources: 27 million boe

o  Prospective resources from overlying reservoirs: 203 million net unrisked boe (68 million boe risked with a weighted-average 33% chance of success)

· Preparations are well underway for the commencement of a high impact three-well drilling programme to further delineate the scale of the project.

Williston Basin, North Dakota, U.S. (non-operated assets)

· Following the completion of several discrete acquisitions, the Company now has a cash-generative non-operated portfolio with working-interests in 219 wells in the Williston Basin, North Dakota, U.S.

· First quarter 2022 sales from the portfolio were over 1,600 barrels of oil equivalent per day (net to Zephyr) with corresponding revenues of US$11.5 million.

· Non-operated portfolio expected to have turnover of US$35-40 million in 2022, providing significant operating cash flow available for reinvestment into the Paradox project development.

Financial

· The Group reports a net profit after tax for the year ended 31 December 2021 of US$0.8 million, reflecting the initial cashflows from its non-operated asset portfolio.

· Revenues for the year from the non-operated asset portfolio were US$6 million with a gross profit of US$3.3 million.

· At 31 May 2022, the Group had cash and cash equivalents of US$11.9m (which includes cash receipts from the non-operated portfolio for the month of May 2022 which were received in early June 2022).

Corporate

· In February 2022, the Company announced that it had raised a further US$17.4 million (before expenses) through the placing of new Ordinary Shares in the Company, along with raising US$28 million through a senior debt facility. The net proceeds from these debt and equity instruments were used to complete the Group's US$36 million acquisition of non-operated assets in the Williston Basin and to fund further drilling activity across the portfolio.

· In line with the Company's ESG objectives, Zephyr achieved carbon-neutrality across its operational footprint (through the purchase of Verified Emission Reduction credits (or "VERs")) prior to its published goal of 30 September 2021.

Rick Grant, Zephyr's Non-Executive Chairman, said: 

 "The period under review was a time of substantial progress in the ongoing transformation of Zephyr. During this period the Group evolved from a single project exploration company into a self-sustaining, cash generating, oil producing group with a balanced portfolio of operated and non-operated assets located in two established oil producing basins in the U.S.

"The 2022 fiscal year promises to be an equally exciting time for our Shareholders as we aim to bring our State 16-2LN-CC well into commercial production and commence our proposed three well drill programme on the Paradox project. A successful drilling programme will see the Group further defining the Paradox project and materially increasing its reserve base in the project, and expected to deliver significant cashflows. This activity will be fully funded by cashflows from our non-operated asset portfolio in the Williston Basin, North Dakota, U.S. (the "non-operated portfolio"), which was formed during the period under review through a number of discrete acquisitions with the main purpose of funding our proposed activity on the Paradox project.

"Our forthcoming activity across all our operations will be carried out consistent with our core values of being responsible stewards of investors' capital and responsible stewards of the environment."

Notice of AGM

The Annual General Meeting of the Shareholders of the Company will be held at 10 a.m. on 21 July 2022 at the offices of Zephyr Energy plc, First Floor, Newmarket House, Market Street, Newbury, Berkshire, RG14 5DP.

Further details are set out in the notice of AGM. A copy of the Company's annual report and accounts, which includes the notice of AGM, will shortly be available on Zephyr's website, http://www.zephyrplc.com, and posted to Zephyr's Shareholders.

Extension of warrants

In November 2019, certain Directors were issued with warrants to subscribe for Ordinary Shares in the Company at a price of 2 pence per Ordinary Share ("Warrants"). These Warrants were issued in connection with the equity placing that was carried out by the Company and announced on 4 November 2019 (the "Placing"). In the Placing, Chris Eadie (Finance Director of Zephyr) invested £10,000, and in accordance with the terms of the Placing, he was issued 454,545 Warrants. Origin Creek Energy LLC ("OCE") invested £480,000 and was issued with 21,818,182 Warrants. The shareholders and directors of OCE are Rick Grant, the Chairman of Zephyr, and Colin Harrington, the CEO of Zephyr. Colin Harrington is indirectly the controlling shareholder of OCE.

On 22 November 2021 the exercise period for these Warrants was extended until 30 June 2022. However, due to continued circumstances beyond their control these directors have not been able to exercise their Warrants and therefore the Independent Directors (Gordon Stein and Tom Reynolds) have agreed to an extension of the exercise period for these Warrants for a further six months until 31 December 2022.

The agreement to extend the exercise date of the Warrants held by OCE and Chris Eadie is a related party transaction pursuant to rule 13 of the AIM Rules for Companies. Accordingly, the Independent Directors of Zephyr (Gordon Stein and Tom Reynolds) consider, having consulted with the Company's nominated adviser, that the terms of the transaction are fair and reasonable insofar as the Company's shareholders are concerned.

Contacts:

Chairman's Statement

Overview

The period under review was a time of substantial progress in the ongoing transformation of Zephyr. During this period the Group evolved from a single project exploration company into a self-sustaining, cash generating, oil producing group with a balanced portfolio of both operated and non-operated assets located in two established oil producing basins in the U.S.

I am incredibly proud of what was achieved during the period, and we remain fully committed to our primary goal of opening up the next prolific onshore U.S. oil and gas play through the systematic development of our flagship project in the Paradox Basin, Utah, U.S. (the "Paradox project").

The 2022 fiscal year promises to be an equally exciting time for our Shareholders as we aim to bring our State 16-2LN-CC well into commercial production and commence our proposed three well drill programme on the Paradox project. A successful drilling programme will see the Group further defining the Paradox project, will deliver significant cashflows, and will see the Group materially increasing its reserve base in the project. This activity will be fully funded by cashflows from our non-operated asset portfolio in the Williston Basin, North Dakota, U.S. (the "non-operated portfolio"), which was established during the period under review, and since, through a number of discrete acquisitions with the main purpose of funding our proposed activity on the Paradox project.

Our forthcoming activity across all our operations will be carried out consistent with our core values of being responsible stewards of investors' capital and responsible stewards of the environment.

Background

Our goals for 2021 were simple but ambitious. We were determined to transform the Group into a well-capitalised hydrocarbon producer, with healthy cashflows and significant growth potential. I am delighted to report that 2021 saw us deliver on all these key objectives.

Our results are even more remarkable when one considers that they were achieved in spite of the backdrop of the second year of the global pandemic. I was thoroughly impressed that our management team and contractors dealt with the extraordinary circumstances in such a positive and effective way, and always with a view to ensuring the welfare of our people and the minimal disruption to our announced timeframes. That we achieved so much during a time of significant market instability, particularly for energy companies, is testament to their abilities and performance and I am extremely grateful for their efforts.

Operational activity

After many years of investment in the Paradox project, it was gratifying that the Group was able to make material progress towards unlocking the potential considerable value of the project during the period. In particular, we saw the first flowing hydrocarbons at the State 16-2LN-CC well from the Cane Creek reservoir target during our highly successful well test. This well test exceeded management's pre-drill estimates and achieved a proven rate-constrained production high of 1,083 barrels of oil equivalent per day ("boepd"), with internal modelling indicating potential flow rates of 2,100 boepd once it is no longer rate-constrained. The well test clearly demonstrated that 16-2LN-CC is both a sizeable and potentially profitable well, and it endorsed Zephyr's strategy of the proposed wider development of the Paradox project.

Zephyr's position within the Paradox Basin was also given a significant boost in 2021 when the United States Bureau of Land Management (the "BLM") approved the formation of a new 25,000-acre Federal Unit, known as the White Sands Federal Unit (the "WSU"), which incorporated all of the Group's leases covered by its historic 3D seismic survey. This provides us with increased security of tenure and an excellent long-term framework for the development of our lease acreage, including the lease on which the State 16-2LN-CC well is situated. 

The ultimate scale and resource potential of the Paradox project was further demonstrated with the completion of an updated independent reserves and resource evaluation, conducted by Sproule International Limited ("Sproule"), the key findings of which were published in April 2022 (the "CPR"). Following the success of the State 16-2LN-CC well, the CPR saw the first proven reserves booked for the Paradox project, with a 2P figure of 2.1 million net barrels of oil equivalent ("boe"). In addition, the CPR saw the doubling of our 2C resource estimates across the Cane Creek reservoir with 27 million net boe, up from 12.3 million boe reported in the Group's previous CPR on the Paradox project that was carried out in 2018.

The plan for the Paradox project for the remainder of the current financial year is to recommence production from the State 16-2LN-CC well, with gas volumes produced being utilised by a co-located crypto-mining facility, and to commence our proposed three well drilling campaign to further delineate the scale and production potential of the project. At the time of writing, we expect to have the State 16-2LN-CC in production by the end of September, and we are making final preparations for our fully funded three well campaign which is due to commence in the coming weeks.

 A key accomplished objective for 2021 was to grow production and positive cash flow for the Group via a combination of our existing portfolio and acquisitions. The rapid growth of our portfolio of non-operated production assets in the Williston Basin, through a number of discrete acquisitions, was a major development in helping us achieve this objective. Our ability to self-fund the upcoming Paradox drilling campaign is the result of successfully executing this strategy of building out our cash generative non-operated portfolio to ensure the organic development of the Paradox project.

Our non-operated portfolio, which currently consists of working-interests in 219 wells (the vast majority of which are currently in production), is expected to provide US$35-40 million of revenue, net to Zephyr, in 2022. In Q1 2022, Zephyr's revenues from the non-operated portfolio were US$11.5 million, resulting in operating cashflows to the Group of US$9.8 million, demonstrating our ability to self-finance the operational activity across our portfolio.

Environmental, Social and Governance ("ESG")

In a year that saw COP26 hosted in Glasgow bringing The Paris Agreement on climate change into ever sharper focus, Zephyr demonstrated its commitment to play its part in this essential global effort. We will always aspire to have ESG credentials that are amongst best in class. This was no more evident than when we achieved, ahead of schedule, our stated target of "net-zero" operational carbon impact. This was done primarily through our programme of purchasing Verified Emission Reduction credits ("VERs"), designed to mitigate all Scope 1 carbon emissions and was an initiative that was unanimously supported by the Company's Board of Directors ("Board").

Followers of Zephyr will be familiar with our commitment to stewardship of both the natural environment and Shareholder capital at the core of all our activity. Prudent and careful cash management and ESG focus were clearly in evidence during the period under review and remain the central tenet of our philosophy. The Board firmly believes this is not only the right way to run the Group but the approach that will ensure our ongoing success on behalf of all stakeholders. Good environmental and operational performance, supported by the appropriate levels of governance is the optimal way to drive superior investor returns. The progress made in 2021 was a clear sign of our firm intent to operate within these key principals and we intend to ensure that they remain embedded at the heart of the Group.

Conclusion

On behalf of the Board, I would like to thank everyone within Zephyr for their unswerving hard work and commitment during this transformational period. I would also like to extend my heartfelt gratitude to our Shareholders and advisers for their continued support. Due to the achievements of 2021, we can look to the future with a high degree of confidence and excitement as we continue in our pursuit of building a Group of which all our stakeholders can be proud.

RL Grant

22 June 2022

Strategic report

PRINCIPAL OBJECTIVES AND STRATEGIES

Zephyr Energy plc is an Oil & Gas ("O&G") exploration and production group operating in the Rocky Mountain region of the U.S.

The Group's stated mission is to open up the next prolific onshore U.S. oil and gas play through the development of its flagship Paradox project. The two core values of the Group are to be responsible stewards of investors' capital and responsible stewards of the environment.

To achieve this mission, the Group has prioritised:

· constructing a team with significant experience in the U.S./Rocky Mountain O&G sector, with a particular focus on operations, development, governance, finance, merger and acquisition and turnaround experience;

· a sharpening of focus - we are wholly focused on responsible Exploration and Production ("E&P") investment in the Rocky Mountain region and have exited all other legacy sectors and geographies;

· the development of a non-operated asset portfolio that provides cashflow to be reinvested in the Paradox project;

· the redoubling of ESG efforts, including corporate governance compliance, ensuring carbon-neutrality across our operations, and proactive engagement with the communities in which we operate;

· the leveraging of partnerships (such as the U.S. Department of Energy, experienced operators in the Basins in which we operate, and private equity investors);

· the design and build of a technology-led acquisition process which can rapidly assess opportunities of further interests through acquisition, farm-in agreements or joint venture arrangements; and

· tight financial control and cash conservation.

REVIEW OF OPERATIONS AND FUTURE DEVELOPMENTS

Background

As outlined in the Chairman's Statement, the period under review has been one of extraordinary progress and transformation for Zephyr.

During this period the Group has achieved multiple operational milestones, most notably with the first flowing hydrocarbons from our flagship Paradox project and with the construction of our cash generating non-operated portfolio.

The Group's operated asset is in the Paradox Basin where it holds a 37,613-acre leasehold and, following the initial drilling success during the year, the Group is expecting its first commercial production from its State 16-2LN-CC well by the end of the third quarter of this year, with gas volumes produced being utilised by a co-located crypto-mining facility which is currently under development. The Group is also well underway with the planning of a three-well drill programme which will commence in the coming weeks to further delineate the scale and production potential of the project.

The Group's non-operated production comes from working-interests in wells across the Bakken and Three Forks formations in the Williston Basin, North Dakota. Zephyr currently has working-interests in 219 wells and Q1 2022 sales from the non-operated portfolio was circa 1,600 boepd (net to Zephyr) resulting in corresponding revenues for Zephyr from the portfolio of circa US$11.5 million for the quarter.

The Board's strategy is to recycle the considerable cashflows expected to be generated from the non-operated Williston Basin portfolio into the proposed Paradox development programme, and this organic growth strategy is expected to enable the Group to fully fund the three-well drilling programme on the Paradox project planned for later this year.

In the Board's opinion the Group's asset portfolio is ideally positioned, with the cash generating, non-operating portfolio providing Shareholders with an engine that can drive the development of the Paradox project and help unlock its potential considerable upside. Set out below is a detailed summary of the progress made across both our operated and non-operated portfolios during the period under review.

Paradox project - operated asset

Background

Having completed the comprehensive restructuring of the Paradox project in 2020, which primarily involved overhauling the existing joint venture partnership and securing additional tenure for the most attractive project acreage, the key task for the 2021 financial year was to commence operations on the ground and to finally begin the process of delivering value from the project after many years of significant investment.

The securing of a US$2 million U.S. Government grant in late 2020 enabled us to proceed with the drilling of the State 16-2 well and this was the catalyst for the considerable progress on the project in the period under review.

The State 16-2 well was completed in January 2021 having been successfully drilled to a measured depth of 9,745 feet total depth ("TD"). Drilling operations were safe and effective, conducted in accordance with Covid-19 related guidance and restrictions, and were completed well within the Group's forecast timeframe.

The objective was to drill and set casing at 6,450 feet measured depth ("MD") in order to provide a host wellbore for a future horizontal side track. This goal was achieved within thirteen days from spud which represented a marked improvement over historical drilling efforts in this part of the Paradox Basin. This reduction in drilling time represented a major operational success and demonstrated that the cost of future development wells could be materially reduced from our earlier estimates, thereby improving the overall potential value of the Paradox project for Shareholders.

Our secondary objective was to acquire a significant amount of new data to improve our understanding of our Paradox acreage. We were pleased to report that Zephyr's data acquisition programme secured the following:

· approximately 113 feet of continuous whole core across the historically productive Cane Creek reservoir interval - the first whole Cane Creek core ever to be retrieved in the northern part of the Paradox Basin;

· rotary side wall cores in eleven shallower exploration targets; and

· gamma ray, neutron density, resistivity, formation litho scanner and sonic wireline log data across the bulk of the Paradox Formation, which secured significant additional petrophysical data.

Following the completion of drilling and data acquisition operations, the State 16-2 well was temporarily plugged at 6,450 feet TD, and left stable and for future re-use as a lateral wellbore host. 

Decision to proceed with State 16-2LN-CC lateral well

The core and log data acquired from the State 16-2 Cane Creek reservoir both corroborated and supported the Board's long-held view that the Paradox project has the potential to be a project of considerable scale.

On 15 March 2021, Zephyr announced a detailed update on the Paradox project, which included confirmation of evidence of hydrocarbon saturation across the entirety of the continuous core acquired from the Cane Creek reservoir. When integrated with the recently acquired log data, existing 3D seismic data, and geologic and regional analogue analysis, the resulting analysis gave the Board strong justification for advancement to the next phase of the project. The Board therefore elected to proceed with detailed planning for the near-term drilling of the lateral well, and following the successful completion of a US$13.9 million fundraise in April 2021, the Group was fully funded to commence the drilling of the lateral portion of the well.

Drilling of the State 16-2LN-CC lateral well

Drilling operations commenced in July 2021, ahead of Zephyr's forecast timeline and, in August 2021 the Group announced that the well was successfully drilled to a TD of 14,370 feet at which point a full suite of wireline logs was run and production casing was set.

Drilling operations achieved their main objective of hitting the Cane Creek reservoir target and staying within that reservoir across the entire lateral portion of the well. In addition, there was evidence of hydrocarbon charge across the entirety of the Cane Creek lateral, as well as in multiple overlying reservoirs.

With the setting of production casing, we were confident of having secured an excellent well bore platform from which to complete the well and test production from the Cane Creek reservoir.

Results from the State 16-2LN-CC data evaluation and diagnostic fracture injection test ("DFIT")

Following the completion of the lateral well, the Group reported its results from the interpretation of the data acquired during drilling operations and the Board was particularly pleased that wireline data suggested that 85 per cent of the lateral had the potential to be completed for well testing and production, with additional positive data suggesting porosity and permeability estimates equivalent to other producing basins with prolific hydraulic stimulated resource potential ("HSRP") development, as well as mud gas mass spectrometry evidence suggesting the presence of oil, gas and condensate with corresponding apparent low water saturations.

Based on the positive data received, the Board therefore elected to initiate a DFIT to provide additional insight into the potential for successful hydraulic stimulation on our acreage position. As the State 16-2LN-CC is the first horizontal well in this part of the Paradox Basin, the ability to develop a strong understanding of reservoir mechanical properties was crucially important to help assess the series of options for wider potential development.

In early September 2021, the Group announced the results from the DFIT, during which a 3 feet interval at the toe of the lateral was perforated and hydraulically stimulated.

The results from the DFIT were highly encouraging and suggested high formation pressure (a strong positive indicator of reservoir drive), permeability consistent with other prolific resource plays, and demonstrable evidence of hydrocarbons flowing into the well after stimulation. In addition, the DFIT provided rock mechanical data (including lithostatic gradient, effective stress and fracture propagation data) which was subsequently interpreted and provided valuable insight to assist with completion design.

In all, the results of the DFIT, combined with the significant amount of data previously gathered from the well, indicate that the State 16-2LN-CC had the potential to be an excellent "proof of concept" location for an HSRP test. 

On that basis, the Board unanimously approved proceeding with a HSRP completion at the State 16-2LN-CC.

First hydrocarbons produced from Paradox project

The HSRP completion commenced on 18 October 2021 and the Group subsequently announced that the operation was successfully completed. The well was stimulated in fourteen separate stages across 4,020 feet of horizontal lateral wellbore. The stimulation utilised a total of 40,000 barrels of water, 2.4 million pounds of sand and a cross linked gel fluid, all in line with pre-completion forecasts.

On 11 November 2021, the Board was delighted to announce the first flowing hydrocarbons from the State 16-2 LN-CC well which represented a significant historical and operational milestone for the Group, particularly as this was the first horizontal well in the wider Paradox Basin to flow hydrocarbons using a modern hydraulically stimulated completion.

The Group carried out 23 days of safe and successful production testing on the well and it demonstrated the potential to drain a larger hydrocarbon resource and with stronger economics than initially forecast by the Group.

Key conclusions from State 16-2 LN CC completion

· During the test, the well averaged rate-constrained daily rates of 716 boepd, with rate-constrained highs of 1,083 boepd achieved with limited pressure drawdown which was incredibly encouraging.

· Initial simulation modelling suggests possible plateau rates of 2,100 boepd are possible when the well is fully equipped and no longer rate-constrained. The test was rate-constrained to minimise flow assurance issues from salt deposition in the well bore. Future flow assurance issues are expected to be mitigated when the well's final completion equipment is installed.

· Gas rates are substantially higher than expected, with modelling suggesting the well is capable of production plateau rates of 10 million square cubic feet of gas per day and 500 boepd of liquids.

· Initial data from the production test suggests the State 16-2LN-CC has a single well potential Estimated Ultimate Recovery ("EUR") of 2.65 million barrels of oil equivalent ("mmboe"), significantly higher than the Group's pre-drill estimates of up to 0.85 mmboe.

· Not only does this successful production test indicate the potential for a highly profitable single well, but the Board also believes the test will lead to a substantial reduction in development risk across our acreage while allowing for a future systematic development of the project - one with relatively predictable well distribution within both the Cane Creek reservoir as well as across the multiple overlying reservoirs.

Following the completion of the production testing, Zephyr commissioned the independent reserve consulting firm Sproule to complete a Competent Persons Report ("CPR") to assess the Group's reserves across both the Cane Creek reservoir and the eight overlying reservoirs.

Competent Persons Report

The previous CPR on the Paradox project was completed in 2018 by Gaffney Cline & Associates ("2018 CPR"). In April 2022, the Group announced the results from Sproule's CPR.

Sproule audited the crude oil, natural gas, and field condensate reserves and contingent resources and the associated future net revenue attributable to the WSU and Cane Creek DSU ("CC DSU") with an effective date of March 31, 2022. Sproule also conducted an audit of the Prospective Resources attributable to the WSU on the same date.

The Board was delighted with the conclusions drawn by Sproule, which both demonstrate the impact of our recent drilling success and which further highlight the substantial potential scale and profitability of the Paradox project.

The key findings were as follows:

· 2P Reserves: First Paradox Basin Proved Reserves of 2.1 million boe, based on the State 16-2 LN-CC

· 2C Resources: 27 million boe - more than double the 2C Resources in the 2018 CPR

· Prospective resources from overlying reservoirs: 203 million net unrisked boe (68 million boe risked with a weighted-average 33% chance of success ("CoS"))

Combined with Zephyr's Williston Basin non-operated portfolio, Zephyr's total 2P Proved Reserves now have an estimated net present value at a ten per cent discount rate ("NPV-10") of over US$111 million (up from zero value ascribed in 2018) with substantial multiples of additional upside potential from success cases related to its contingent and prospective resources. 

In determining the NPV-10 for the reserves and resources, Sproule utilised its March 31, 2022 price forecast for both oil and gas which includes a West Texas Intermediate ("WTI") oil price forecast of US$93/barrel ("bbl") in 2022, US$83/bbl in 2023, and US$73/bbl in 2024, with a further US$5.00 per barrel deduction for price differential. For the gas price forecast, Sproule used a Henry Hub gas price of US$5.00/per million British thermal units ("mmbtu") in 2022, US$4.25/mmbtu in 2023, and US$3.25/mmbtu, with a further gas price differential of US$1.25 per million standard cubic feet ("mscf") reduction from Henry Hub, a heating value of 1000 btu per mscf and a shrinkage of 5% for losses due to surface facilities. Prices and costs are escalated at 2.0% per annum until the price doubles, and are then held flat. 

The CPR marked a key milestone for the Group, further outlining the potential value in the Paradox project and due to the success of the State 16-2 LN-CC well, and our acquisition of proved reserves around the Cane Creek field, the Group was able to book Proved Reserves on the Paradox project for the first time.

Due to the early-stage nature of the Paradox Basin resource play, the range of outcomes for Zephyr's Utah assets remains large. Both Zephyr and Sproule identified uncertainties due to limited data across the areas planned for development by the Group. These include fluid composition and compressibility, water production, continuity of geomechanical properties across the reservoir and their impact on hydraulic fracture characteristics, and stimulated area around a well (well drainage area). The Group plans to utilise its upcoming three well drilling campaign to further quantify both the risks and upside presented by these uncertainties.

Formation of the WSU Federal Unit

Following the successful State 16-2 LN-CC drilling programme, the Group was also thrilled to report that the BLM had approved the formation of a new 25,000-acre Federal Unit to be operated by Zephyr. The new unit, the WSU, incorporates the Group's existing leases covered by its historic 3D seismic survey, including the lease on which the State 16-2LN-CC well is situated. 

The WSU approval, effective October 2021, was another key milestone in the Group's ongoing development of the Paradox project. By consolidating over twenty separate leases into one overarching land agreement, Zephyr can focus on an optimal long-term development plan for the project as a whole, rather than maintaining its lease position in an ad-hoc fashion.

If the State 16-2 LN CC well is determined to be capable of delivering paying quantities of hydrocarbons, or if a second well is drilled on the WSU acreage within the next twelve months, the WSU will be extended beyond the initial 36-month extension currently approved by the BLM.

Next steps

Following the successful completion of State 16-2LN-CC well test and after taking into account the conclusions of the CPR, the Group intends to commence a high impact three-well drilling programme later this year to further delineate the scale of the project. This will include:

· one delineation/development well targeting the Cane Creek reservoir in Zephyr's 25,000-acre WSU (the "State 36-2 LNW-CC" well);

· one exploration well targeting Clastic 9 to see the zones potential to host a resource play (the "State 36-3 LN-C9 well); and

· one delineation/development well in the historically prolific Cane Creek Field (new acreage south of the WSU)

Drilling permits for the drilling programme have been submitted, all necessary on-site surveys have been completed and negotiations continue with rig vendors.

Zephyr has also commenced work to equip the State 16-2LN-CC well for commercial production, and on 7 June 2022, the Group announced its plans to recommence production by the end of September 2022. Liquid volumes produced from the well will be trucked and sold to refineries in Utah, and produced gas volumes will be sold to fuel onsite power generators which in turn will provide electricity for the co-located crypto-mining facility.

The Group plans to fund the initial investment required to launch the initial 1 megawatt ("MW") crypto-mining facility (capital expenditure forecast to be less than US$2 million) from existing cash resources or via third party investment, with facility capital payback expected in under two years at current crypto-currency prices. CryptoKnight Energy, an experienced operator of oil industry co-located crypto mining operations, will serve as the general contractor for the construction and operation of the mining facility.

Following the testing of the 1MW facility, Zephyr may elect to build up to 4MW of power generation and crypto-mine facilities on the pad. Zephyr is evaluating a range of third-party investment options in the event it elects to expand the crypto-mining infrastructure.

Over the longer-term, the Group expects to tie its gas production from the Paradox project into the nearby gas export infrastructure recently purchased by Dominion Energy Inc. ("Dominion") a Fortune 500 Company which currently services over seven million customers in the U.S. Dominion has made public its plans to refurbish and expand the natural gas infrastructure running across Zephyr's acreage, and is expected to be available to accept gas volumes from Zephyr's wells in 2023.

Williston Project - Non-operated asset

In January 2021, Zephyr stated that one of its key goals for the year was to establish production and positive cashflow either through its existing portfolio (the Paradox project), via acquisition, or through a combination of both. In the period under review, and since, the Group has delivered on this goal and the Board is incredibly proud that, following a series of acquisitions, the Group now has a non-operated portfolio that delivered sales of over 1,600 boepd, net to Zephyr, in Q1 2022, with corresponding revenues of US$11.5 million for the quarter.

The establishment of our non-operated portfolio began in March 2021, during a period of lower commodity prices, and with the integration of our recent US$36 million acquisition (completed in February 2022), our non-operated portfolio is expected to have a turnover of US$35-40 million in 2022, providing the Group with free cash flow to support of Paradox project development plans.

In order to lock in cashflow to develop our Paradox asset and meet our funding commitments, in April 2022, the Group hedged just under half of its forecast 2022 production at more than US$98 per barrel of oil.

Zephyr currently has working-interests in 219 wells, the vast majority of which are currently in production with multiple additional wells expected to be put in production over the next six months. The working-interests are in prime locations, and the majority of the wells are operated by Whiting Petroleum Corporation ("Whiting"), a leading Williston Basin producer.

Acquisitions

The non-operated portfolio has been carefully crafted and has been achieved through five discrete acquisitions, culminating in the completion of a transformative US$36 million acquisition (the "acquisition") in February 2022. This acquisition nearly tripled the Group's existing non-operated production from its four previous acquisitions.

The US$36 million acquisition was a game-changer for the Group, providing a stable foundation of low-decline production and cash flows from 163 gross producing wells. In addition, 18 drilled but uncompleted wells ("DUCs") are expected to be brought online in the near term and 47 additional gross undeveloped locations are expected to provide meaningful upside for many years to come. The acreage is also highly complementary to the Group's other interests in the Williston Basin.

The key benefits of the Acquisition are as follows:

· A diversified, low-decline production base with established history and stable cash flows

· Near term growth from DUC wells currently being brought online

· Potential to hedge a significant portion of the existing production at attractive prices to lock in returns and provide downside protection

· Excellent complement to (and funding source for) the less mature, higher upside Paradox Basin development

In order to fund the Acquisition, in January 2022, the Group undertook an equity fundraise of £12.8 million and secured a US$28 million senior debt facility from a long-established North Dakota-based commercial bank.

The Group's non-operated portfolio continues to perform well ahead of the Board's forecasts and expectations, in part due to the current high commodity price environment.

Production update

Q1 2022 sales from the Group's non-operated portfolio averaged circa 1,600 boepd net to Zephyr, up from 548 boepd in Q4 2021. 

During Q1 2022, Zephyr sold 144,540 boe and net sales to Zephyr were as follows:

Oil: 109,940 barrels ("bbls") at an average sales price of US$90.11 /bbl

Natural Gas: 114,096 million cubic feet ("mmcf") at an average sales price of US$5.40 /mcf

Natural Gas Liquids: 15,584 bbls at an average sales price of US$64.19 per bbl

Q1 2022 revenues totalled US$11.5 million net to Zephyr, and Q1 2022 average operating expenditure was US$11.87 boe demonstrating the high profit margin realised from the hydrocarbons sold during the period.

16 new producing wells from Zephyr's existing portfolio are expected to be brought online over the next six months.

Hedging

In April 2022, the Group hedged just under half of its forecast non-operated production over the next two years. Using an average hedged production price of US$98 for the remainder of the year and US$90 flat for the remainder of its anticipated production, the Group forecasts a range of US$35-40 million in revenue from production for FY 2022 from its non-operated portfolio based on forecast production range of 500,000 - 550,000 boe during the year. 

ENVIRONMENTAL, SOCIAL AND GOVERNANCE ("ESG")

The Board is unanimously committed to ensuring that every action and investment decision the Group's makes is in line with our core values of being responsible stewards of investors' capital and responsible stewards on the environment. This includes the following points of focus:

· we will continue to protect the Group, safeguard its existing asset base and position it for attractive growth opportunities;

· we will continue to seek creative and beneficial funding opportunities in an effort to unlock value from our existing asset portfolio, as evidenced by the U.S. Government funding we received for our recent drilling programme on the Paradox project;

· we will continue to adopt a disciplined focus on growth via the acquisition of producing or near-term development opportunities in the Rocky Mountain region. Even in this unusual economic environment, we believe that attractive, value-additive acquisitions are available and may be acquired using non-traditional funding structures;

· we will continue with our programme of tight financial controls and cash preservation which will enable the Group to continue trading effectively; and

· we will continue to ensure management and the Board are aligned with our Shareholders through significant ownership of shares.

The Board is proud of how Zephyr conducted its operations in the period under review and we will always strive to adhere to our core values

A major milestone was achieved when the Zephyr announced carbon-neutrality across its operational footprint prior to its published goal of 30 September 2021.As an integral part of this undertaking, Zephyr is collaborating with the Prax Group ("Prax"), a British multinational independent oil refining, trading, storage, distribution and retail conglomerate dealing in crude oil, petroleum products and bio-fuels, headquartered in London, United Kingdom. Prax, which has trading offices in London, Singapore and the U.S., worked with Zephyr to measure, reduce and mitigate greenhouse gas ("GHG") emissions across Zephyr's businesses, with mitigation efforts primarily focused on the purchase of VERs from reputable pre-vetted developers of sustainable projects. This exercise includes Zephyr's current corporate activity, its non-operated production assets in the Williston Basin, North Dakota, U.S., and Paradox project activity.

In addition to the environmental benefits that will result from Zephyr's efforts to reach carbon-neutrality, the Group anticipates that this approach will also yield economic benefits including expanded access to a wider group of potential institutional investors, as total ESG-focused assets under management are currently estimated to be over US$30 trillion globally. Moreover, the average cost of capital for companies with committed ESG and decarbonisation initiatives has been shown to be demonstrably less than that of traditional resource companies. The Board believes that incremental regulatory benefits may also materialise from Zephyr's actions.

Partnership with Purified Resources ("Purified")

In September 2021, the Group announced the formation of a partnership with Purified for the identification and execution of additional non-operated acquisitions. Purified's principals have substantial experience in the Williston Basin, a basin in which they previously helped assemble and close over US$70 million of non-operated asset acquisitions and associated CAPEX for a private equity-backed vehicle. 

Purified has assisted and/or co-invested with Zephyr in all its Williston acquisitions that it has closed in the period under review, and their team will have the right to continue to co-invest in future transactions. The newly formed partnership provides Zephyr with significant land and business development expertise directly in Zephyr's geographic region of focus.

Commencement of trading on OTCQB Venture Market

In July 2021, the Group's announced that its Ordinary Shares had been approved to trade on the OTCQB Venture Market ("OTCQB") in the U.S.

The Board believes that cross-trading on the OTCQB will increase liquidity and significantly enhance the ability of U.S. based investors to access and trade Zephyr shares during a period in which the Company is actively expanding its U.S. asset base.

FINANCIAL REVIEW

Income statement

The Group reports a net profit after tax of US$0.8 million or a profit of 0.08 cents per Ordinary Share for the year ended 31 December 2021 (2020: net loss after tax of US$2.3 million or 0.66 cents per Ordinary Share). The Group generated revenue of US$6 million from its non-operated asset portfolio (2020: nil), and made a gross profit of US$3.3 million (2020: nil).

Administrative expenses for the year were US$2.7 million (2020: $1.6 million) highlighting the ramp up of the Group's operations following the pandemic, and the expansion of operations to provide the capacity and capability to develop both he operated and non-operated asset portfolios.

Balance sheet

Total investment in the Group's exploration and evaluation assets as at 31 December 2021 was US$22.8 million (2020: US$13.9 million) reflecting continuing investment in the Paradox project.

Total investment in property, plant and equipment as at 31 December 2021 was US$11.2 million (2020: US$0.03 million) reflecting the acquisition of the Group's non-operated assets in the Williston Basin.

Cash and cash equivalents as at 31 December 2021 were US$1.8 million (2020: US$3.9 million). During the year, the Company raised gross proceeds of US$13.9 million (2020: US$2.9 million) through the placing of new Ordinary Shares in the Company. In November 2021 the Group secured debt funding of US$4.1 million (2020: nil) to enable it to pay a US$3 million deposit in respect of a proposed acquisition which subsequently completed in February 2022.

In February 2022, the Company announced that it had raised a further US$17.4 million (before expenses) through the placing of new Ordinary Shares in the Company, along with raising US$28 million through a senior debt facility. The proceeds from these debt and equity instruments was used to complete the Group's US$36 million acquisition of non-operated assets in the Williston Basin and to fund further activity on the Paradox project.

At 31 May 2022, the Group had cash and cash equivalents of US$11.9m (this includes cash receipts from the non-operated portfolio for the month of May 2022 which were received in early June 2022).

Significant decisions made

During the year under review and post year end, the Directors completed four discrete acquisitions of non-operated assets. The decisions to proceed with the acquisitions and the corresponding debt and equity funding were logical decisions made to ensure the advancement of the Paradox project and were unanimously deemed by Board members to be in the best interests of the Company. Details of the acquisitions can be found in the relevant sections of this Annual Report.

In addition, and to facilitate the drilling of the State 16-2 well, the Company completed an equity fundraise through the issue of Ordinary Shares in the Company. In arriving at the decision to proceed with the fundraise the Directors considered the cash position of the Group, the dilution impact that the respective fundraises would have on the existing Shareholders of the Company and the importance of progressing the Paradox project. After due consideration, the Directors unanimously considered the fundraise to be in the best interests of the Company and its Shareholders.

We would like to thank all Shareholders for their continued support.

On behalf of the Board

JC Harrington

Chief Executive Officer

22 June 2022

CONSOLIDATED INCOME STATEMENTFor the year ended 31 December 2021

CONSOLIDATED BALANCE SHEET As at 31 December 2021

CONSOLIDATED STATEMENT OF CHANGES IN EQUITYFor the year ended 31 December 2021

CONSOLIDATED CASH FLOW STATEMENTFor the year ended 31 December 2021

NOTES TO THE FINANCIAL STATEMENTS

For the year ended 31 December 2021

The figures for the years ended 31 December 2021 and 2020 do not constitute statutory accounts within the meaning of Section 434 of the Companies Act 2006. The figures for the year ended 31 December 2021 have been extracted from the statutory accounts for that year on which the auditor has issued an unqualified audit report (and did not draw attention to any matters by way of emphasis) which have yet to be delivered to the Registrar of Companies.

The figures for the year ended 31 December 2020 have been extracted from the statutory accounts for that year which have been delivered to the Registrar of Companies. The auditor issued an unqualified audit report.

No statement has been made by the auditor under Section 498(2) or (3) of the Companies Act 2006 in respect of either of these sets of accounts.

The consolidated financial statements have been prepared in accordance with International Accounting Standards in conformity with the requirements of the Companies Act 2006 ("IAS"). The information in this preliminary statement has been extracted from the audited financial statements for the year ended 31 December 2021 and does not contain all the disclosures required by accounts prepared in accordance with IAS and as such, does not contain all the information required to be disclosed in the financial statements prepared in accordance with IAS.

1. CORPORATE INFORMATION

Zephyr Energy plc (the "Company" and, together with its subsidiaries, the "Group") is domiciled and incorporated in the United Kingdom under the Companies Act 2006 and is limited by shares. The address of the registered office is 20-22 Wenlock Road, London, N1 7GU.

In July 2021, the Company's Ordinary Shares were approved to trade on the OTCQB Venture Market ("OTCQB") in the U.S. under the ticker ZPHRF. The ability to trade in the Company's existing Ordinary Shares on AIM is not affected by the OTCQB facility.

Zephyr Energy plc is a technology-led Evaluation & Production ("E&P") company focused on the delivery of superior economic returns through responsible resource development from its carbon-neutral portfolio of operated and non-operated assets in the Rocky Mountain region of the U.S.

2. ADOPTION OF NEW AND REVISED STANDARDS

STANDARDS ADOPTED DURING THE YEAR

The Group has adopted all of the new or amended Accounting Standards and interpretations issued by the International Accounting Standards Board ("IASB") that are mandatory and relevant to the Group's activities for the current reporting period.

The following new and revised Standards have been adopted but have not had any material impact on the amounts reported in these financial statements:

· Amendment to IFRS 16 - Covid -19 related rent concessions beyond 30 June 2021

· Amendments to IFRS 9, IAS 39, IFRS 7, IFRS 4 and IFRS 16 - Interest rate benchmark reform phase 2

STANDARDS ISSUED BUT NOT YET EFFECTIVE

Any new or amended Accounting Standards or interpretations that are not yet mandatory (and in some cases, had not yet been endorsed by the UK Endorsement Board) have not been early adopted by the Group for the year ended 31 December 2021. They are as follows:

· Amendments to IAS 1 - Classification of liabilities as current or non-current

· Amendments to IFRS 17 - Insurance contracts

· Amendments to IFRS 17 - Initial application of IFRS 17 and IFRS 9 - comparative information

· Amendments to IFRS 3 - Reference to the conceptual framework

· Amendments to IFRS 12 - Deferred tax related assets and liabilities arising from a single transaction

· Amendments to IAS 16 - Property, plant and equipment - proceeds before intended use

· Amendments to IAS 37 - Onerous contracts - cost of fulfilling a contract

· Amendments to IAS 1 and IFRS practice statement 2 - Disclosure of accounting policies

· Amendments to IAS 8 - Definition of accounting estimates

· Annual improvements to IFRS standards 2018-2020

The Directors do not expect that the adoption of these Standards or Interpretations in future periods will have a material impact on the financial statements of the Company or the Group.

3. SIGNIFICANT ACCOUNTING POLICIES

BASIS OF PREPARATION

On 31 December 2020, IFRS as adopted by the European Union at that date was brought into UK law and became UK-adopted International Accounting Standards, with future changes being subject to endorsement by the UK Endorsement Board. The Group transitioned to UK-adopted International Accounting Standards in the Group's consolidated financial statements and the Company financial statements on 1 January 2021. This change constitutes a change in accounting framework. However, there is no impact on recognition, measurement or disclosure in the period reported as a result of the change in framework.

The financial statements have been prepared in accordance with UK-adopted International Accounting Standards and with the requirements of the Companies Act 2006 as applicable to companies reporting under those standards.

The financial statements have been prepared on the historical cost basis. Historical cost is generally based on the fair value of the consideration given in exchange for assets.

The financial statements are presented in United States dollars ("US$"). All amounts have been rounded to the nearest thousand, unless otherwise indicated.

As described below, the Directors continue to adopt the going concern basis in preparing the consolidated financial statements.

The accounting policies set out below have, unless otherwise stated, been applied consistently to all periods presented in these financial statements.

The preparation of the financial statements in compliance with UK-adopted international accounting standards requires management to make estimates and exercise judgement in applying the Group's accounting policies. The significant judgments made by the Directors in the application of these accounting policies that have significant impact on the financial statements and the key sources of estimation uncertainty, are disclosed in note 4.

GOING CONCERN

The Directors have prepared cash flow forecasts for the Group for the period to 31 December 2023 based on their assessment of both the discretionary and the non-discretionary cash requirements of the Group during this period and based on a range of sensitivities and scenarios.

These cash flow forecasts include its normal operating costs for operations together with all committed development expenditure, including the impact of the acquisition completed in February 2022. The forecasts also take account of the Company's recent fundraise and borrowings in February 2022, and the near-term CAPEX requirements for, and the forecast revenues from, the Paradox project and the non-operated portfolio of assets, together with proposed committed development expenditure. The cash flow forecasts indicate that the Group currently has sufficient cash resources to service these costs over the forecast period.

The Group will meet its working capital requirements and financing costs from existing cash resources and future cash flows generated from its producing assets. At the year end, the Group had cash and cash equivalents amounting to US$1.8 million (2020: US$3.9 million).

The Directors continue to adopt the going concern basis in preparing the consolidated financial statements.

BASIS OF CONSOLIDATION

The consolidated financial statements incorporate the financial statements of the Company and its subsidiary undertakings (together, "the Group") made up to 31 December each year.

Subsidiary undertakings are those entities controlled directly or indirectly by the Company. Control is achieved when the Company is exposed to, or has rights to, variable returns from its involvement with the entity and has the ability to affect those returns through its power over the entity.

The results of subsidiaries acquired or disposed of during the year are included in the consolidated income statement from the date on which control is transferred to the Group or, up to the date that control ceases, as appropriate. Where necessary, adjustments are made to the financial statements of subsidiaries to bring accounting policies used into line with those used by the Group.

The Group applies the acquisition method to account for business combinations. The consideration for each acquisition is measured at the aggregate of the fair values (at the date of exchange) of assets given, liabilities incurred or assumed, and equity instruments issued by the Group in exchange for control of the acquire.

All intra-group transactions, balances, income and expenses are eliminated on consolidation.

BUSINESS COMBINATIONS AND ASSET ACQUISITIONS

In accordance with the requirements of IFRS 3 Business combinations, the Group performs an assessment of each acquisition to determine whether the acquisition should be accounted for as an asset acquisition or a business combination. For each transaction, the Group may elect to apply the concentration test as permitted by the amendment to IFRS 3 to determine if the fair value of assets acquired is substantially concentrated in a single asset (or a group of similar assets). If this concentration test is met, the acquisition qualifies as an acquisition of a group of assets and liabilities, and not of a business.

The requirements of IFRS 3 are applied once it is determined that a business has been acquired. Under IFRS 3, a business is defined as an integrated set of activities and assets conducted and managed for the purpose of providing a return to investors. A business generally consists of inputs, processes applied to those inputs, and resulting outputs that are, or will be, used to generate revenues.

When less than the entire interest of an entity is acquired, the choice of measurement of the non-controlling interest, either at fair value or at the proportionate share of the acquiree's identifiable net assets, is determined on a transaction by transaction basis.

INVESTMENTS IN SUBSIDIARY UNDERTAKINGS

Long term investments representing interests in subsidiary undertakings are stated at cost less any provision for impairment in the value of the non-current investment. 

EXPLORATION AND EVALUATION ASSETS

The Group applies the full cost method of accounting for Exploration and Evaluation ("E&E") costs, having regard to the requirements of IFRS 6 Exploration for and Evaluation of Mineral Resources. Under the full cost method of accounting, costs of exploring for and evaluating mineral resources are accumulated by reference to appropriate cost centres being the appropriate licence area but are tested for impairment on a cost pool basis as described below.

E&E assets comprise costs of (i) E&E activities that are on-going at the balance sheet date, pending determination of whether or not commercial reserves exist and (ii) costs of E&E that, whilst representing part of the E&E activities associated with adding to the commercial reserves of an established cost pool, did not result in the discovery of commercial reserves.

Costs incurred prior to having obtained the legal rights to explore an area are expensed directly to the income statement as they are incurred.

All costs of E&E are initially capitalised as E&E assets. Payments to acquire the legal right to explore, costs of technical services and studies, seismic acquisition, exploratory drilling and testing are capitalised as intangible E&E assets.

Intangible costs include directly attributable overheads together with the cost of other materials consumed during the exploration and evaluation phases.

Treatment of E&E assets at conclusion of appraisal activities

Intangible E&E assets related to each exploration licence/project are carried forward until the existence (or otherwise) of commercial reserves has been determined. If commercial reserves have been discovered, the related E&E asset are assessed for impairment on a cost pool basis as set out below and any impairment is recognised in the income statement. The carrying value, after any impairment loss, of the relevant E&E assets is then reclassified as development and production assets.

Intangible E&E assets that related to E&E activities that are determined not to have resulted in the discovery of commercial reserves remain capitalised as intangible E&E assets at cost less accumulated amortisation, subject to meeting a pool-wide impairment test in accordance with the accounting policy for impairment of E&E assets set out below. Such E&E assets are amortised on a unit-of-production basis over the life of the commercial reserves of the pool to which they relate.

Impairment of exploration and evaluation assets

E&E assets are assessed for impairment when facts and circumstances suggest that the carrying amount may exceed its recoverable amount. Such indicators include, but are not limited to, those situations outlined in paragraph 20 of IFRS 6 Exploration for and Evaluation of Mineral Resources and include the point at which a determination is made as to whether or not commercial reserves exist.

Where there are indications of impairment, the E&E assets concerned are tested for impairment. Where the E&E assets concerned fall within the scope of an established full cost pool, the E&E assets are tested for impairment together with all development and production assets associated with that cost pool, as a single cash generating unit.

The aggregate carrying value is compared against the expected recoverable amount of the pool, generally by reference to the present value of the future net cash flow expected to be derived from production of commercial reserves. Where the E&E assets to be tested fall outside the scope of any established cost pool, there will generally be no commercial reserves and the E&E assets concerned will generally be written off in full.

If the recoverable amount of a cash-generating unit is estimated to be less than its carrying amount, the carrying amount of the cash-generating unit is reduced to its recoverable amount. An impairment loss is recognised immediately in profit or loss.

When an impairment loss subsequently reverses, the carrying amount of the cash-generating unit is increased to the revised estimate of its recoverable amount, but so that the increased carrying amount does not exceed the carrying amount that would have been determined had no impairment loss been recognised for the cash-generating unit in prior years. A reversal of an impairment loss is recognised immediately in profit or loss.

The Group considers each area of oil and gas exploration, on a geographical basis to be a separate cost pool and therefore aggregates all specific assets for the purposes of determining whether impairment of E&E assets has occurred.

GRANT INCOME

Government grants are recognised only when there is a reasonable assurance that the Group will comply with any conditions attached to the grant, and that the grant will be received.

Claims under government grant programmes related to income are deducted in reporting the related expense. If the grants are specific to exploration projects, the Group records grants receivable by deducting the funds received from the carrying value of the Group's exploration and evaluation assets.

PROPERTY, PLANT AND EQUIPMENT

Oil and gas properties

Oil and gas properties are stated at cost, less accumulated depreciation and any accumulated impairment losses. The initial cost of an asset comprises its purchase price or construction cost, any costs directly attributable to bringing the asset into operation, and the initial estimate of the asset retirement obligation. The purchase price or construction cost is the aggregate amount paid and the fair value of any consideration given to acquire the asset.

Production and development assets are depleted using the unit-of-production method based on production for the period divided by the Group's estimated total proved and probable reserve volumes (before royalties) of the geographic region concerned. Production and reserves volumes for natural gas are converted at the energy equivalent of six thousand cubic feet of natural gas to one barrel of oil. Estimates of future development costs for developing the proved and probable reserves are included in the depletion base.

Plant and machinery and right-of-use assets

Plant and machinery and right-of-use assets are stated at cost less accumulated depreciation and any accumulated impairment losses. The cost of an item of property, plant and equipment comprises its purchase price and any costs directly attributable to bringing the asset into use.

Depreciation is recognised so as to write off the cost of assets less their residual values over their useful lives at the following rates:

Plant and machinery straight-line over 5 years

Right-of-use assets straight-line over the shorter of the lease term and the useful life of the underlying asset

The estimated useful lives, residual value and depreciation method are reviewed at the end of each reporting period, with the effect of any changes in estimate accounted for on a prospective basis.

An item of property, plant and equipment is derecognised upon disposal or when no future economic benefits are expected to arise from the continued use of the asset. Any gain or loss arising on the disposal or retirement of an item of property, plant and equipment is determined as the difference between the sales proceeds and the carrying amount of the asset and is recognised in profit or loss. 

Impairment of property, plant and equipment

In accordance with the requirements of IAS 16 Impairment of assets at each reporting date, the Directors assess whether indications exist that the carrying value of an asset may be impaired. If there are indicators of impairment the Directors estimate the asset's recoverable amount. An assets recoverable amount is the higher of an asset's, or cash generating unit's, fair value less costs to sell and its value-in-use, and is determined on a portfolio basis, based on geographical location.

Where the carrying amount of an asset or cash-generating unit exceeds its recoverable amount, the Directors consider the asset impaired and writes it down to its recoverable amount. In assessing value-in-use, the Directors discount the estimated future cash flows 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. In determining fair value less costs to sell, the Directors consider recent market transactions, if available. If no such transactions can be identified, the Directors will utilise an appropriate valuation model.

JOINT ARRANGEMENTS

The Company is party to a joint arrangement when there is a contractual agreement that sets out the terms of the relationship over the relevant activities of the Company and at least one other party.

Management has a legal degree of control over these joint operating arrangements through Joint Operating Agreements.

The Company classifies its interests in joint arrangements as joint operations where the Company has both the right to assets and obligations for the liabilities of the joint arrangement. It accounts for its interests in joint operations by recognising its share of assets and liabilities, revenues and expenses in accordance with its contractually conferred rights and obligations.

The Company accounts for its own assets, liabilities and cash flows measured in accordance with the terms of the Joint Operating agreement and the accounting treatment reflects the agreement's commercial effect.

Where the percentage ownership in joint arrangements changes during a reporting period, the arrangement is reassessed to ensure it is still appropriately classified, and the Company's share of income and expenses is adjusted prospectively from the date of change.

FOREIGN CURRENCIES

For the purpose of the consolidated financial statements, the results and financial position are expressed in United States dollar, which is the presentation currency for both company and consolidated financial statements.

In preparing the financial statements of the individual companies, transactions in currencies other than the functional currency of each group company ("foreign currencies") are translated into the functional currency at the rates of exchange prevailing on the dates of the transactions. At each reporting date, monetary assets and liabilities that are denominated in foreign currencies are retranslated into the functional currency at the rates prevailing on the reporting date. Non-monetary assets and liabilities carried at fair value that are denominated in foreign currencies are translated at the rates prevailing at the date when the fair value was determined. Non-monetary items that are measured in terms of historical cost in a foreign currency are not retranslated.

Foreign exchange differences are recognised in the profit or loss in the period in which they arise, except for foreign exchange differences on monetary items receivable from or payable to a foreign operation for which settlement is neither planned nor likely to occur and which, therefore, form part of the net investment in the foreign operation. Foreign exchange differences arising on the translation of the Group's net investment in foreign operations are recognised as a separate component of Shareholders' equity via the statement of other comprehensive income. On disposal of foreign operations and foreign entities, the cumulative translation differences are recognised in the income statement as part of the gain or loss on disposal. 

For the purpose of presenting company and consolidated financial statements, the assets and liabilities of the Company, and the Group's subsidiaries, which have a functional currency other than United States dollar, are translated using exchange rates prevailing at the end of each reporting period. Income and expense items are translated at the average exchange rates for the period, unless exchange rates fluctuate significantly during that period, in which case the exchange rates at the date of transactions are used. Foreign exchange differences arising are recognised in other comprehensive income and accumulated in equity. Equity items are translated at the exchange rates at the date of transactions and foreign exchange differences arising are accumulated directly in equity.

On the disposal of a foreign operation (i.e. a disposal of the Group's entire interest in a foreign operation, a disposal involving loss of control over a subsidiary that includes a foreign operation or loss of joint control over a jointly controlled entity that includes a foreign operation), all of the accumulated exchange differences in respect of that operation attributable to the Group are reclassified to profit or loss. Where there is no change in the proportionate percentage interest in an entity then there has been no disposal or partial disposal and accumulated exchange differences attributable to the Group are not reclassified to profit or loss.

Fair value adjustments arising on the acquisition of a foreign operation are treated as assets and liabilities of the foreign operation and translated at the rate of exchange prevailing at the end of each reporting period. Exchange differences arising are recognised in equity.

RETIREMENT BENEFITS

The Group makes contributions to the personal pension schemes for some of its employees and Directors. Payments to these schemes are charged as an expense in the income statement in respect of pension costs payable in the year.

TAXATION

The tax expense represents the sum of the tax currently payable for the year and deferred tax.

The tax currently payable is based on taxable profit for the year. Taxable profit differs from profit as reported in the consolidated income statement because it excludes items of income or expense that are taxable or deductible in other years and items that are never taxable or deductible. The Group's liability for current tax is calculated using tax rates that have been enacted or substantively enacted by the reporting date.

Deferred tax is recognised on temporary differences between the carrying amounts of assets and liabilities in the consolidated financial statements and the corresponding tax bases used in the computation of taxable profit. Deferred tax liabilities are generally recognised for all taxable temporary differences and deferred tax assets are generally recognised for all deductible temporary differences to the extent that it is probable that taxable profits will be available against which those deductible temporary differences can be utilised. Such deferred tax assets and liabilities are not recognised if the temporary difference arises from goodwill or from the initial recognition (other than in a business combination) of other assets and liabilities in a transaction which affects neither the taxable profit nor the accounting profit.

Deferred tax liabilities are recognised for taxable temporary differences associated with investments in subsidiaries and interests in joint ventures, except where the Group is able to control the reversal of the temporary difference and it is probable that the temporary difference will not reverse in the foreseeable future. Deferred tax assets arising from deductible temporary differences associated with such investments and interest are only recognised to the extent that it is probable that there will be sufficient taxable profits against which to utilise the benefits of the temporary differences and they are expected to reverse in the foreseeable future.

The carrying amount of deferred tax assets is reviewed at each reporting date and reduced to the extent that it is no longer probable that sufficient taxable profits will be available to allow all or part of the assets to be recovered.

Deferred tax liabilities and assets are measured at the tax rates that are expected to apply in the period in which the liability is settled or the asset realised, based on tax rates that have been enacted or substantively enacted at the reporting date.

Current and deferred tax are recognised in profit or loss, except when they relate to items that are recognised in other comprehensive income or directly in equity, in which case, the current and deferred tax are also recognised in other comprehensive income or directly in equity respectively. Where current tax or deferred tax arises from the initial accounting for a business combination, the tax effect is included in the accounting for the business combination.

Deferred tax assets and liabilities are offset when there is a legally enforceable right to set off current tax assets against current tax liabilities and when they relate to income taxes levied by the same taxation authority and the Group intends to settle its current tax assets and liabilities on a net basis.

INVESTMENTS AND OTHER FINANCIAL INSTRUMENTS

Recognition of financial assets and financial liabilities

Financial assets and financial liabilities are recognised on the Group's Balance Sheet when the Group becomes a party to the contractual provisions of the instrument, and are initially measured at fair value. Transaction costs are included as part of the initial measurement, except for financial assets at fair value through profit or loss.

Investments and other financial assets are subsequently measured at either amortised cost or fair value depending on their classification. Classification is determined based on both the business model within which such assets are held and the contractual cash flow characteristics of the financial asset unless an accounting mismatch is being avoided.

Financial liabilities are subsequently measured at either amortised cost or fair value.

Derecognition of financial assets and financial liabilities

The Group derecognises a financial asset only when the contractual rights to cash flows from the asset expire, or it transfers the financial asset and substantially all the risks and rewards of ownership of the asset to another entity. If the Group neither transfers nor retains substantially all the risks and rewards of ownership and continues to control the transferred asset, the Group recognises its retained interest in the asset and an associated liability for the amount it may have to pay. If the Group retains substantially all the risks and rewards of ownership of a transferred financial asset, the Group continues to recognise the financial asset and also recognises a collateralised borrowing for the proceeds received.

On derecognition of a financial asset and financial liability a gain or loss is recognised in profit or loss.

Impairment of financial assets

The Group recognises a loss allowance for expected credit losses on financial assets which are measured at amortised cost. The measurement of the loss allowance depends upon the Group's assessment at the end of each reporting period as to whether the financial instrument's credit risk has increased significantly since initial recognition, based on reasonable and supportable information that is available without undue cost or effort to obtain.

Where there has not been a significant increase in exposure to credit risk since initial recognition, a 12-month expected credit loss allowance is estimated. This represents a portion of the asset's lifetime expected credit losses that is attributable to a default event that is possible within the next 12 months. Where a financial asset has become credit impaired or where it is determined that credit risk has increased significantly, the loss allowance is based on the asset's lifetime expected credit losses. The amount of expected credit loss recognised is measured on the basis of the probability weighted present value of anticipated cash shortfalls over the life of the instrument discounted at the original effective interest rate.

Trade and other receivables are measured at initial recognition at fair value, and are subsequently measured at amortised cost using the effective interest method, less any allowance for expected credit losses.

The Group has applied the simplified approach to measuring expected credit losses which uses a lifetime expected loss allowance. To measure the expected credit losses, trade receivables are grouped on the basis of days overdue.

Cash and cash equivalents comprise cash-in-hand and on-demand deposits.

Trade and other payables are initially measured at their fair value, and are subsequently measured at amortised cost using the effective interest rate method.

An equity instrument is any contract that evidences a residual interest in the assets of the Group after deducting all of its liabilities. Equity instruments issued by the Group are recognised at the proceeds received, net of direct issue costs.

The costs of an equity transaction are accounted for as a deduction from equity to the extent they are incremental costs directly attributable to the equity transaction that would otherwise have been avoided.

Warrants

Warrants issued are classified within Shareholders' equity and are valued at fair value on issuance. The Group uses the Black-Scholes model to estimate fair value. Upon exercise, the consideration received is recorded as an increase in share capital.

LEASES

The Group assesses whether a contract is or contains a lease, at inception of the contract. The Group recognises a right-of-use asset and a corresponding lease liability with respect to all lease agreements in which it is the lessee, except for short-term leases (defined as leases with a lease term of 12 months or less) and leases of low value assets. For these leases, the Group recognises the lease payments as an operating expense on a straight-line basis over the term of the lease.

The lease liability is presented as a separate line in the Balance Sheet and is subsequently measured by reducing the carrying amount to reflect the lease payments made.

The right-of-use assets comprise the initial measurement of the corresponding lease liability, lease payments made at or before the commencement day and any initial direct costs. They are subsequently measured at cost less accumulated depreciation and impairment losses.

Right-of-use assets are depreciated over the shorter of the period of the lease term and the useful life of the underlying asset. 

The right-of-use assets are presented within property, plant and equipment in the consolidated and company Balance Sheet.

The Group applies IAS 36 Impairment of assets to determine whether a right-of-use asset is impaired.

BORROWINGS

Borrowings are recognised initially at fair value, net of any transaction costs incurred. Borrowings are subsequently carried at amortised cost. Any difference between the proceeds (net of transaction costs) and the redemption value is recognised in the Consolidated Statement of Income over the period of the borrowings using the effective interest method, if applicable.

Interest on borrowing is accrued as applicable to each class of borrowing.

PROVISIONS

Provisions are recognised when the Group has a legal or constructive obligation, as a result of past events, for which it is probable that an outflow of economic resources will result and that outflow can be reliably measured.

The amount recognised as a provision is the best estimate of the consideration required to settle the present obligation at the end of the reporting period, considering the risks and uncertainties surrounding the obligation. When a provision is measured using the cash flow estimated to settle the present obligation, its carrying amount is the present value of those cash flows.

Where a liability for the retirement of a well, removal of production equipment and site restoration at the end of the production life of a well exists, the Group recognises a liability for asset retirement. Provision for asset retirement is recognised in full when the related assets are installed or acquired, and are then reassessed at the end of each reporting period.

The provision recognised is calculated as the net present value of the Group's share of the expenditure expected to be incurred at the end of the life of the asset. The cost of recognising the decommissioning provision is included as part of the cost of the relevant asset and is, therefore, charged to the income statement in accordance with the Group's policy for depreciation of property, plant and equipment or for impairment of exploration and evaluation assets, depending upon the stage of the assets at the time of retirement.

 The unwinding of the discount on the decommissioning liability is included as accretion of the provision and is presented in finance costs in the Consolidated Statement of Income.

The Group recognises changes in estimates prospectively, with corresponding adjustments to the liability and the associated non-current asset.

SHARE-BASED PAYMENTS

The Group has applied the requirements of IFRS 2 Share-based Payment for all grants of equity instruments.

The Group operates an equity-settled share option plan and a share-based compensation plan in respect of certain Directors, employees and consultants. The Group also issues warrants to certain advisors which are classed as share-based payments. Equity-settled share-based payments are measured at fair value (excluding the effect of non-market based vesting conditions) at the date of grant. The fair value of the service received in exchange for the grant of options/warrants and equity is recognised as an expense. The fair value determined at the grant date of equity-settled share-based payment is expensed on a straight-line basis over the vesting period, based on the Group's estimate of shares that will eventually vest and adjusted for the effect of non-market based vesting conditions.

The fair value of option and warrant grants are measured using the Black Scholes model for non-performance-based options. The expected life used in the model has been adjusted, based on management's best estimate, for the effect of non-transferability, exercise restrictions and behavioural considerations.

The grant by the Company of options and share-based compensation plans over its equity instruments to the employees of subsidiary undertakings in the Group is treated as a capital contribution. The fair value of employee services received, measured by reference to the grant date fair value, is recognised over the vesting period as an increase to investment in subsidiary undertakings, with a corresponding credit to equity in the parent entity accounts.

REVENUE RECOGNITION

Natural Gas, NGLs and Oil

Revenue is comprised of the fair value of the consideration received or receivable from the sale of natural gas and crude oil products in the ordinary course of the Group's activities and is recognized when control is transferred to the purchaser. This is generally met when title passes from the Group to its customer. Revenue from oil and gas production represents the Group's share.

The Group sells its petroleum and natural gas revenue pursuant to variable-price contracts with terms of generally one year or less. The transaction price is based on the commodity index price at the point of title transfer and may include adjustments for quality, location or other factors depending on the contract terms. The Group delivers volumes of petroleum and natural gas product to the respective counterparty throughout the contract period. The Group evaluates its arrangements with third parties and partners to determine if the Group acts as the principal or as an agent. In making this evaluation and concluding that it acts as a principal, management considers if the Group obtains control of the product delivered, which is indicated by the Group having the primary responsibility for the delivery of the product, having the ability to establish prices or having inventory risk.

Revenue is recognized when a customer obtains legal title to the product, which is when volumes are physically transferred to the contract counterparty at a point of sale.

SEGMENTAL REPORTING

Operating segments are reported in a manner consistent with the internal reporting provided to the chief operating decision maker. The chief operating decision maker, who is responsible for allocating resources and assessing performance of the operating segments and making strategic decisions, has been identified as the Board of Directors.

4. CRITICAL ACCOUNTING JUDGEMENTS AND KEY SOURCES OF ESTIMATION UNCERTAINTY

In the application of the Group's accounting policies, which are described in note 3, the Directors are required to make judgements, estimates and assumptions about the carrying amounts of the assets and liabilities that are not readily apparent from other sources. The estimates and associated assumptions are based on historical experience and other factors that are considered to be relevant. Actual results may differ from these estimates.

The estimates and underlying assumptions are reviewed on an on-going basis. Revisions to accounting estimates are recognised in the period in which the estimate is revised if the revision affects only that period or in the period of the revision and future periods if the revision affects both the current and future periods.

The following are the critical judgements and estimations that the Directors have made in the process of applying the Group's and Company's accounting policies and that have the most significant effect on the amounts recognised in the financial statements:

CRITICAL JUDGEMENTS

Exploration and evaluation assets - Group

The decision to transfer assets from exploration and evaluation assets to property, plant and equipment is based on the estimated proved and probable reserves which are in part, used to determine a project's technical feasibility and commercial viability.

There has been no transfer of exploration and evaluation assets during the year ended 31 December 2021.

Business combinations and asset acquisitions - Group

The determination of whether a transaction is a business combination or an asset acquisition is based on management's assessment of each individual transaction based on the criteria of IFRS 3 Business combination.

If the initial concentration test is met, then the acquisition is accounted for as an asset acquisition and no further analysis is required. If the initial test is not met, the acquisition is considered to be a business combination and the Group applies the acquisition method to account for the recognition and measurement of identifiable assets acquired, the liabilities assumed, any non-controlling interest and, if applicable, goodwill or a gain on the transaction.

During the year ended 31 December 2021, the Group acquired non-operated working interests in a number of wells in the Williston Basin, North Dakota, U.S. The Directors consider that the acquisitions meet the requirements of the concentration test and, therefore, each of the transactions have been accounted for as an acquisition of assets and are presented within property, plant and equipment. See note 14.

ESTIMATIONS

Impairment and impairment reversals - Group

The recoverable amounts of CGUs and individual assets have been determined based on the higher of value-in-use calculations and fair values less costs to dispose. These calculations require the use of estimates and assumptions including information on forecasted oil and gas commodity prices, expected production volumes, quantity of reserves, discount rates, as well as future development costs, operating costs and royalty costs. Key assumptions in the determination of cash flows from reserves include reserves estimated by the Group's independent third party reserve evaluators. It is possible that any or all of these key assumptions may change, which may then impact the estimated values of the oil and gas properties and then require a material adjustment to the carrying value of E&E assets and property, plant and equipment. Significant management judgement is required to analyse internal and external indicators of impairment or historical impairment reversals. The Group monitors internal and external indicators of impairment relating to its tangible and intangible assets.

Recoverability of loans to subsidiary undertakings - Company only

The Company has outstanding loans from its directly held subsidiaries which have then made a number of loans to indirectly held subsidiaries as the primary method of financing the activity of those subsidiaries. The principal loans are shown in the Company balance sheet on the basis that the loans incur interest at a commercial rate according to the Group's inter-company loan policy, which is being rolled up until such time as the subsidiaries are in a position to settle.

In accordance with IFRS 9 Financial instruments, as the subsidiary undertakings cannot repay the loans at the reporting date, the Board has made an assessment of expected credit losses ("ECL"). The Group has not made any provision for impairment of its U.S. non-current assets and is expecting to generate profits in the future. As a result, the Board do not consider that any further provision for ECL is required and, therefore, subject to the recognition of exchange differences, a cumulative lifetime ECL of US$31.8 million has been recognised at 31 December 2021 (2020: US$32.1 million).

At 31 December 2021, the Company has total loans in its directly held subsidiaries of US$66.9 million (2020: US$49 million). See note 15.

Reserve estimates

Reserves are estimates of the amount of natural gas, NGLs and oil product that can be economically and legally extracted from the Group's properties. To calculate the reserves, significant estimates and assumptions are required about a range of geological, technical and economic factors, including quantities, production techniques, recovery rates, production costs, transport costs, commodity demand, commodity prices and exchange rates.

Estimating the quantity and/or grade of reserves requires the size, shape and depth of fields to be determined by analysing geological data, such as drilling samples. This process may require complex and difficult geological judgments and calculations to interpret the data.

Given the economics used to estimate reserve changes from year to year and, because additional geological data is generated during the course of operations, estimates of reserves may change from time to time.

Decommissioning

Decommissioning costs will be incurred by the Group at the end of the operating life of certain facilities and properties. The ultimate decommissioning costs are uncertain and cost estimates can vary in response to many factors including changes to relevant regulatory requirements, the emergence of new restoration techniques or experience at other production sites. The expected timing and amount of expenditures can also change, for example in response to changes in reserves or changes in laws and regulations or their interpretation. In addition, the Group determines the appropriate discount rate at the end of each reporting period. The Group uses a risk-free discount rate to determine the present value of the estimated future cash outflows to settle the obligation and may change in response to numerous market factors. As a result, there could be significant adjustments to the provisions established which would affect future financial results.

5. SEGMENTAL INFORMATION

When considering the requirements of IFRS 8 Operating segments, the Board of Directors have determined that the Group has one main operating segment, the exploration, development and production of O&G resources based in the U.S. As a result, no segmental information is presented.

6. OTHER INCOME

During the year ended 31 December 2020, the Group was in receipt of the business rates grant introduced by the UK government to provide financial support to businesses during the COVID-19 pandemic. No further support has been required or received by the Group during the year ended 31 December 2021.

7. FINANCE COSTS

8. PROFIT/(LOSS)BEFORE TAXATION

The profit/(loss) before taxation for the year has been arrived at after charging/(crediting):

9. AUDITOR'S REMUNERATION

Amounts payable to the external auditors and their associates in respect of both audit and non-audit services:

10. STAFF COSTS

The average monthly number of employees (including Executive Directors) was:

Their aggregate remuneration comprised:

1A proportion of staff costs were deferred during the year ended 31 December 2020. See note 28.

Included within Group wages and salaries is US$0.15 million (2020: US$0.1 million) capitalised to exploration and evaluation assets, and US$ 0.02 million (2020: US$ nil) capitalised to property, plant and equipment.

Included within Company wages and salaries is US$0.27 million (2020: US$0.2 million) which relates to the activities of its subsidiary entities.

Refer to the Directors' Report for details regarding the remuneration of the highest paid Director.

11. TAXATION

The charge for the year can be reconciled to the profit/(loss) per the income statement as follows:

The Group did not have any tax payable in the U.S. due to the utilisation of prior year tax losses.

There has been no impact due to changes in UK taxation rates during the years reported. The enacted UK corporation tax rate of 25% forms the basis for the UK element of the deferred tax calculation, following the UK budget in 2021 when the chancellor announced an increase to the main rate of corporation tax in the UK to 25% from April 2023.

Unrelieved tax losses carried forward, as detailed in note 21, have not been recognised as a deferred tax asset as the Group has not yet shown sustainable profitability and there is currently insufficient evidence that the asset will be recoverable in the foreseeable future. The losses must be utilised in relation to the same operations.

12. PROFIT/(LOSS) PER ORDINARY SHARE

Basic profit/(loss) per Ordinary Share is calculated by dividing the net profit/(loss) for the year by the weighted average number of Ordinary Shares in issue during the year. Diluted profit/(loss) per Ordinary Share is calculated by dividing the net profit/(loss) for the year by the weighted average number of Ordinary Shares in issue during the year adjusted for the dilutive effect of potential Ordinary Shares arising from the Company's share options and warrants.

Due to the losses incurred in the year ended 31 December 2020, there was no dilutive effect from the share options or warrants.

At 31 December 2021, 2.8 million share options and 15 million warrants were excluded from the diluted number of shares as they were anti-dilutive.

The calculation of the basic and diluted profit/(loss) per Ordinary Share is based on the following data:

13. EXPLORATION AND EVALUATION ASSETS

In July 2021, the Group announced that it had acquired an additional 12,260 acres in the Paradox Basin at a cost of US$ 0.1 million, following which, the Group will operate a total of 37,613 gross acres in the Paradox Basin, the majority of which the Group holds as operator with a 75% working interest.

In October 2021, the Group announced that the BLM had approved the formation of a new 25,000-acre Federal Unit to be operated by the Group. The new unit, the White Sands Federal Unit ("WSU") incorporates all the Group's existing leases, including the lease on which the State 16-2 LN CC well is situated. The entire 25,000-acre land position around the State 16-2 LN CC well will now be held for a minimum of 36 months from 25 October 2021, without any lease expiry.

U.S. Department of Energy Funding

During the year, the Group received grant funding of US$0.3 million (2020: US$1.8 million), together with an additional agreed sum of US$0.1 million, from the EGI as described above. In accordance with IAS 20, the carrying value of the Group's exploration and evaluation assets have been presented net of the funds received.

The Group is the operator of the well and is responsible for all planning and drilling activity. The Group and its 25 per cent partner RSOC continue to be the sole working interest owners in the leasehold and of the vertical well.

Impairment

The Directors considered the indicators of impairment as set out in IFRS 6 and have satisfied themselves that there was no requirement to perform an impairment test at 31 December 2021 and, as a result, no provision for impairment has been made in respect of these assets at 31 December 2021 (2020: US$ nil). See note 4.

14. PROPERTY, PLANT AND EQUIPMENT

The Group depreciation and depletion charge has been allocated to the income statement as follows:

Acquisitions

During the year ended 31 December 2021, the Group acquired non-operated working interests in a number of projects located in the Williston Basin, North Dakota, U.S.

Williston-Whiting acquisition

In March 2021, the Group completed the acquisition of non-operated working interests, ranging from 16.8% to 27.2% in five wells, one producing and 4 DUCs. The wells are operated by Whiting Petroleum and target the middle Bakken reservoir in Mountrail County, North Dakota U.S. The initial cost of the acquisition was US$350,000, with an additional payment of US$3.9 million being paid to the operator in respect of historical CAPEX obligations on the project.