REG - Indus Gas Limited - Annual Financial Report
30/09/2025 07:00
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RNS Number : 3099B Indus Gas Limited 30 September 2025
30 September 2025
Indus Gas Limited
("Indus" or the "Company")
Audited Final Results for the 12 months ended 31 March 2025
Indus Gas Limited (AIM:INDI), an oil & gas exploration and development
company, announces its full year audited results for the 12 months to 31 March
2025, which will be made available on its website and sent to shareholders.
The Company will shortly publish its notice of annual general meeting and a
further announcement will be made in due course.
-ENDS-
For further information please contact:
Indus Gas Limited
Jonathan Keeling
+44 (0) 7380 425 886
Strand Hanson Limited (Nominated & Financial Adviser and Broker)
Ritchie Balmer, Rory Murphy
+44 (0) 20 7409 3494
Overview
Indus Gas Limited ("Indus" or "Company") is engaged in oil and gas development
in Block RJ-ON/6, Rajasthan, through its wholly owned subsidiaries iServices
Investment Limited, Mauritius and Newbury Oil Company Limited, Cyprus. The
Block currently measures an area of 2,176 sq. km and lies onshore in the
highly prospective mid Indus Basin. The first discovery in the Block was made
in 2006 and the first commercial production commenced in 2010. Production
started from a small area in the SSG and SSF field in the year 2021.
Highlights
· Gas supplies to Gail are continuing under an interim term sheet. The
Company is expecting a Production Sharing Contract (PSC) extension. A new Gas
Sale and Purchase Agreement (GSPA) will be signed after the receipt of the PSC
extension.
OPERATIONAL
§ Continued drilling / workover of wells.
FINANCIAL
§ Total Revenues were US$ 29.65 million (2023-24: US$ 42.93 million).
§ The value of Production, Plant and Equipment has been impaired to US$
776.64 Million (2023-24:US$ 1291.62million) based on an independent valuer's
report and group's estimates. Retained earnings have declined to a retained
loss of US$ 54 million (2023-24: US$ 303.01 million). Deferred Tax liabilities
(net) have decreased to US$ NIL (23-24: US$160.14million)
§ Operating profit for the year decreased to US$ 26.39 million (2023-24: US$
36.56 million).
§ Profit before tax decreased to US$ 26.39 million (2023-24: US$ 36.12
million).
§ Net Investments (before impairment) made in property, plant and equipment
amounting to US$ 18.37 million (2023-24: US$ 70.96 million).
§ All secured bank loans stand fully repaid on time.
Chairman's Statement
The Board would like to extend its sincere appreciation to employees,
shareholders, bankers, and all other stakeholders for their continued loyalty
and support during a challenging year. The Group remains committed to
increasing gas production and offtake, and the management team continues to
focus on executing the long-term strategy of growing reserves and achieving
sustainable commercial production.
The Indian government's emphasis on enhancing domestic gas output to reduce
reliance on costly imports and strengthen energy security aligns with the
Group's strategic objectives. However, the year was not without its
difficulties. Production levels were impacted by operational constraints,
while the Group also recognized impairment losses on the production assets and
property, plant and equipment following a reassessment of future cash flows
and reserve estimates.
Following the lapse of certain rights of GAIL under the Gas Sales and Purchase
Agreement (GSPA) with GAIL on 1 February 2025, the Group recognized income
related to the expiry of make-up gas rights. Although GAIL has initiated
arbitration proceedings, legal advice obtained by the company indicates that
the claims are not sustainable, and considers that it is not probable that an
outflow of resources will be required, therefore no provision has been
recorded.
The Board acknowledges the uncertainty arising from the expiry of key
commercial agreements and the ongoing arbitration. Nonetheless, management
continues to engage constructively with stakeholders to secure long-term
arrangements and stabilize operations. The Group remains focused on navigating
these challenges while preserving value and pursuing growth.
Jonathan Keeling
Chairman
Board of Director's Review
§ We are pleased to announce the consolidated total income aggregating to US$
29.65 million (2023-24: US$ 42.93 million). The value of Production, Plant and
Equipment has been impaired to US$ 776.64 million (2023-24:US$1,292.39
million) based on the third party report and group's estimates. Retained
earnings have transitioned to a retained loss of US$ 54.55 million, compared
to a positive balance of US$ 313.01 million in FY 2023-24, Deferred Tax
liabilities (net) have decreased to US$ NIL. (2023-24 US$ 160.14 million)
Operations
Over the past year, the Group has continued to pursue its strategic objective
of enhancing reserves and progressing their monetization. While operational
activities remained focused on exploration and development, production levels
declined due to various operational and commercial challenges.
Financials
During the financial year, the Group achieved total income of US$ 29.63
million (2023-24: US$ 42.93 million), resulting in reported operating profit
of US$ 26.39 million (2023-24 US$ 36.56 million). The reported loss after tax
was US$ 357.57 million as compared to Profit after tax in the previous year
period 2023-24 US$ 20.19 million.
While the Group is not expected to pay any significant taxes on its income for
many years in view of the 100% deduction allowed on the capital expenses
incurred in the Block, the Company has accrued a Current tax liability of US$
10.25 million (2023-24: US$ 15.75 million) as per IFRS Accounting Standards
requirements.
The net expenditure on the purchase of property, plant & equipment was US$
18.37 million (2023-24: US$ 70.96 million). The property plant and equipment,
including development assets and production assets, increased to US$ 1,309.99
million (2023-24: US$ 1,291.62 million). After impairment Production, plant
and equipment's reduced to US$ 776.14 million(2023-24: US$1291.62 Million)
The current assets (excluding cash and cash equivalent) as of 31 March 2025
stood at US$ 116.78 million (2023-24: US$ 116.87 million), which includes US$
6.90 million (2023-24: US$ 8.94 million) of inventories, US$ 109.24 million
(2023-24: US$ 107.31 million) of receivables from related party and US$ 0.64
million (2023-24: US$ 0.62 million) of trade receivables and other receivable.
The current liabilities of the Company, excluding the related party liability
of US$ 709.60 million (2023-24:US$ 0.01 million) and current portion of
long-term debt of US$ 4.51 million (2023-24: US$ 20.58 million), stood at US$
11.86 million (2023-24: US$ 1.53 million).
As of 31 March 2025, the outstanding unsecured debt from bonds was US$ 164.09
million (2023-24: US$ 164.03 million), of which US$ 4.51 million (2023-24: US$
4.34 million) was categorized as repayable within a year and the remaining US$
159.58 million (2023-24: US$ 159.68 million) has been categorized as a
long-term liability.
Outlook
Over the next twelve months, the Group aims to achieve drilling success across
targeted wells and advance the monetization of its gas reserves. Management
remains focused on securing long-term commercial arrangements, resolving
outstanding contractual matters, and stabilizing production levels. While
recent operational setbacks, including reduced output and asset impairments,
have presented challenges, the Group continues to align its strategy with
India's national priority of enhancing domestic gas production and energy
self-reliance. Efforts will also be directed toward strengthening stakeholder
relationships, optimizing capital deployment, and maintaining financial
discipline to support sustainable
growth.
Jonathan Keeling, Executive Chairman
Board of Directors
JONATHAN KEELING - EXECUTIVE CHAIRMAN
Jonathan was a founding partner and a main board member of Arden Partners plc,
a small and mid-cap institutional stockbroker and Jonathan's career in equity
capital markets spans in excess of 30 years. Prior to Arden, Jonathan worked
at Albert E Sharp, Harris All day and Old Mutual Securities. Jonathan is a
Fellow of the Chartered Institute for Securities and Investment.
ATIQ ANJARWALLA - DIRECTOR
During the year, Mr. Atiq joined the board of director as independent
non-executive director on 3(rd) October 2022.Mr. Atiq is an experience
Lawyer and is a Solicitor of the Supreme Court of England and Wales Advocate
of the High Court of Kenya and a Legal Consultant in Dubai. Atiq has a Master
of Law from Jesus College Cambridge, England. Atiq's legal experience spans
Corporate, Private Client, Banking, Project Finance and Capital Markets.
ELIZABETH POWELL - DIRECTOR
During the year, Mrs. Elizabeth Powell joined the board of director as
independent non-executive director on 7(th) March 2023. Liz's background is
primarily in Human Resources through her work with a major Guernsey based
independent fiduciary. She has a CIPD qualification in HR and has become
skilled in international payroll matters. In recent years, in addition to her
personnel skills, she has taken on directorships in companies employing staff
in the Oil & Gas sector as well as companies owning assets for
international oil companies.
NICHOLAS SAUL - DIRECTOR
During the year, Mr. Nicholas Saul joined the board of director as independent
non-executive director on 7(th) March 2023. Nick started his career as a
Merchant Navy Officer with Texaco in 1980 and has been working in the Oil
& Gas industry since. Today, he owns successful Guernsey business that
manages the employment of thousands working in the hydrocarbons industry as
well over 10,000 mariners. Nick has a BSc in Maritime Commerce, is an
Associate Fellow of the Nautical Institute and a Chartered Member of The
Chartered Institute of Logistics and Transport.
Directors' Report
The Directors present their report and the consolidated financial statements
of Indus Gas Limited ("the Company") and its subsidiaries, iServices
Investments Ltd and Newbury Oil Co. Ltd (collectively the "Group"), which
covers the year from 1 April 2024 to 31 March 2025.
PRINCIPAL ACTIVITY AND REVIEW OF THE BUSINESS
The principal activity of the Company and Group is that of oil and gas
exploration, development and production and other related services.
RESULTS AND DIVIDENDS
The trading results for the year and the Group's financial position at the end
of the year are shown in the attached consolidated financial statements. The
Group has earned a profit before tax of US$26.39 million (2023-24 : US$ 36.12
million) during the year.
§ The value of Production, Plant and Equipment has been impaired to US$
776.14million (2023-24:US$1291.62 million) based on the independent valuer's
report and group's estimates. Retained earnings have declined to a retained
loss of US$ 54 million (2023-24: US$ 303.01 million). Deferred Tax
liabilities (net) have decreased to US$NIL (2023-24: US$ 160.14million).
The Directors have not recommended a dividend for the year 2024-25.(2023-24
Nil)
REVIEW OF BUSINESS AND FUTURE DEVELOPMENTS
A review of the business and likely future developments of the Group are
contained in the Chairman's statement and the Board of Director's review,
given above.
BOARD CHANGES
The Group announces the following changes to its subsidiary boards:
• Ms. Wendy Ramakrishnan has stepped down from the Board effective from 5th
March 2025.
• Mr. Rathee Jugessur has been appointed to the Board effective from 5th
March 2025.
DIRECTORS REMUNERATION
The Directors' remuneration for the year ended 31 March 2025 was:
Particulars Currency Remuneration Remuneration (US$)
Jonathan Keeling £ 100,000 130,133
Atiq Anjarwalla £ 14,620 19,290
Mr. Nicholas Saul £ 5,000 6,506
Mrs. Elizabeth Powell £ 5,000 6,506
Mr. Rathee Jugessur* (w.e.f 05 March 2025) £ - -
Ms. Wendy Ramakrishnan (w.e.f. 04 August 2023)* £ 759 1000
Sangeeta Bissessur* £ 759 1,000
Angelos Alexandrou* € 600 626
Paschalis Magnitis* € 600 626
Total Directors' Remuneration 127,338 165,687
*Directors of subsidiary companies (I Services and Newbury)
The Directors' remuneration for the year ended 31 March 2024 was:
Particulars Currency Remuneration (£) Remuneration (US$)
Jonathan Keeling £ 100,000 126,962
Clive Gibbons (until 26 September 2023) £ 7,000 8,554
Atiq Anjarwalla £ 14,620 18,392
Mr. Nicholas Saul £ 5,000 7,202
Mrs. Elizabeth Powell £ 5,000 7,202
Fareed Soreefan (until 04 August 2023)* £ 260 343
Ms. Wendy Ramakrishnan (w.e.f. 04 August 2023)* £ 499 657
Sangeeta Bissessur* £ 759 1,000
Angelos Alexandrou* € 745 981
Paschalis Magnitis* € 745 981
Total Directors' Remuneration 134,628 172,274
*Directors of subsidiary companies (iServices and Newbury)
The Director remuneration consists of monthly/quarterly compensation as per
the agreed terms. There are no further cash payments or benefits provided to
Directors.
GAS MARKETS IN INDIA
India has a significant deficit of hydrocarbons which we believe will result
in a long-term, steady demand for gas produced by our Block. According to the
Petroleum and Natural Gas Regulatory Board ("PNGRB") Report, Vision 2030,
India's natural gas demand will grow significantly to 746 MMSCM/d (26.3 BCF/d)
by the end of Fiscal 2030. India is expected to have approximately 32,727 km
of natural gas pipeline with a design capacity of 815 MMSCM/d in place by
2030. In order to further boost the consumption of natural gas in the country,
the Government established a Gas Trading Hub/ Exchange (GTHE), where natural
gas can be traded and supplied through a market-based mechanism instead of
multiple formula driven prices. Initial trading has already started on Indian
Gas Exchange.
From April 2024 to March 2025 the gas sale were invoiced at prices at the
highest of US$ 8.90 per MMBTU to the lowest of US$ 7.29 per MMBTU.
FINANCIAL INSTRUMENTS
Details of the use of consolidated financial instruments by the Group are
contained in note 28 to the attached financial statements.
RELATED PARTY TRANSACTIONS
Details of significant related party transactions are contained in note 16 and
note 22 to the attached consolidated financial statements.
INTERNAL CONTROL
The Directors acknowledge their responsibility for the Group's system of
internal control and for reviewing its effectiveness. The system of internal
control is designed to manage the risk of failure to achieve the Group's
strategic objectives. It cannot totally eliminate the risk of failure but will
provide reasonable, although not absolute, assurance against material
misstatement or loss.
GOING CONCERN
The Group's Production Sharing Contract (PSC) expired on 20 August 2024 and
had not been extended as at the date of these consolidated financial
statements. Management has formally applied for an extension of the PSC and
continues to engage with relevant authorities to secure its renewal.
The Gas Sales and Purchase Agreement (GSPA) with the Group's sole customer
expired on 30 September 2024. In its place, the Group entered into an Interim
Term Sheet for gas sales and purchases, which is extendable every six months.
The current Interim Term Sheet has been extended until 31 January 2026
Management remains in active negotiations with the customer to establish a
long-term commercial arrangement. The repeated extensions of the Interim Term
Sheet, along with the customer's operational reliance on gas from the block to
support regional power generation, support the expectation of further
extensions or renewal of the GSPA.
In relation to the GSPA, an arbitration tribunal has been constituted to
address the ongoing dispute. Proceedings are underway, but no final award has
been issued to date. Independent legal advice indicates that an outflow of
economic resources arising from the arbitration is not currently considered
probable. Resolution of the matter is expected to be protracted (refer to Note
24).
Subsequent to the reporting date, the Group has continued to service the
borrowings and has arrangements in place to address maturing obligations.
These include expected internal cash generation and continued financial
support from majority shareholders. Gynia has confirmed that although the
outstanding shareholders loan is contractually repayable on demand, it will
not be recalled within the next 12 months
Management has prepared cash flow forecasts and operating plans that reflect
these arrangements and the Group's available liquidity position.
Based on the factors and forecasts outlined above, management is confident
that the Group will be able to meet its obligations as they become due in the
ordinary course of business. However, despite these mitigating factors, the
expiration of the PSC and the lack of a finalized long-term GSPA introduce a
material uncertainty that could significantly impact the Group's ability to
continue operating as a going concern. Nevertheless, these financial
statements have been prepared on a going concern basis.
DIRECTORS' RESPONSIBILITIES
The Directors are responsible for preparing the Directors' report and
consolidated financial statements for each financial year which give a true
and fair view of the state of affairs of the Group and of the consolidated
statement of comprehensive income of the Group for that year. In preparing
those financial statements the Directors are required to:
o Select suitable accounting policies and apply them consistently;
o Make judgements and estimates that are reasonable and prudent;
o State whether IFRS Accounting Standards as adopted by European Union
have been followed subject to any material departures disclosed and explained
in the financial statements; and
o Prepare consolidated financial statements on a going concern basis
unless it is inappropriate to presume that the Group will continue in
business.
The Directors confirm that the consolidated financial statements comply with
the above requirements.
The Directors are responsible for keeping proper accounting records which
disclose with reasonable accuracy at any time the consolidated financial
position of the Company and of the Group to enable them to ensure that the
consolidated financial statements comply with the requirements of the
Companies (Guernsey) Law, 2008. They are also responsible for safeguarding the
assets of the Group and hence for taking reasonable steps for the provision
and detection of fraud and other irregularities.
The Directors are responsible for maintaining the integrity of the corporate
financial information included on the Group's website. Legislation in Guernsey
governing the preparation and dissemination of financial information may
differ from legislation in other jurisdictions.
To the best of our knowledge and belief:
· The consolidated financial statements have been prepared in
accordance with IFRS Accounting Standards (IFRS), as adopted by the European
Union(EU);
· Give a true and fair view of the financial position and results
of the Group; and
· The consolidated financial statements include an analysis of the
principal financial instruments specific risks and uncertainties faced by the
Group.
AUDITOR
All of the current Directors have taken all steps that they ought to have
taken to make themselves aware of any information needed by the Group's
Auditor for the purposes of their audit and to establish that the Auditor is
aware of that information. The Directors are not aware of any relevant audit
information of which the Auditor is unaware.
By order of the Board
Jonathan Keeling
Risks and Risk Management
In planning our future activities and reacting to changes in our ongoing
business environment, we seek to identify, assess, mitigate and monitor the
risks that we face. Considerable effort is made during our planning process to
reduce and mitigate the various risks to the extent that this is practical and
commercially sound. Ideally large decisions taken early means that any later
adaptation or reaction should be small.
We cannot remove the Group from all risk and the oil and gas industry brings
with it many special challenges in specific risks. What we can and do strive
to achieve is to understand and manage the risk environment we work within.
The Group faces the appraisal, development and production risks of the oil and
gas industry. The business relies on extensive engineering, geological and
geophysical judgements.
As activities on the Block have grown and generated actual data and
experience, we have used this knowledge to reduce these risks. There has been
an increase in the number of wells to find hydrocarbons through the knowledge
gained from almost complete 3D seismic data and analysis of drilling results.
We shall continue to de-risk this area of our operations but the risk of a dry
hole will never reach zero. The risk of mechanical issues or well construction
failing remains. However, with greater standardization of well design and
repetition of activities this has reduced.
We currently depend on one customer for the sale of gas and substantially all
of our revenues. Discussions are on-going to find and develop new customer
relationships.
GAIL has significant financial resources and maintains a strong credit rating
providing comfort in meeting any obligations under our Agreement. Our gas is
purchased at our field and shipped via a GAIL owned pipeline to the power
plant. The pipeline is purpose built and operating well within its design
specification.
The Group has Bonds outstandings. The Amounts were raised during 2018 through
unsecured bonds, which were further re-financed with the additional bond
offering made by the Group in November 2022. The Group has benefited from
consistent support of the majority shareholder particularly reducing the risk
of any funding gaps due to the delay in closing external finance. The
Production Sharing Contract has expired and its renewal is currently pending
Government approval; once approved, it will continue to include cost recovery
and a long-term gas sales contract will be signed to enhance cash flow for
debt servicing and protect lenders.
Our business, revenues and profits may fluctuate with changes in oil and gas
prices. However, the prevailing prices of oil and gas can have some bearing on
new contracts and price revisions.
As per the revised Domestic gas pricing Guidelines, Sales gas price shall be
10 pcr of monthly average of Indian crude basket as notified by PPAC on a
monthly basis from 8th April, 2023. The Gas sale price in the year ended March
2024 ranged from highest of US$ 8.90 per MMBTU to the lowest of US$ 7.29 per
MMBTU.
The oil and gas industry are subject to laws and regulations relating to
environmental and safety matters in exploration for and the development and
production of hydrocarbons. We are bound by the environmental laws and
regulations applicable to India and satisfy and in some areas exceed these
requirements by using good industry practice, trained staff and quality
equipment.
We are committed to upholding procedures to protect the environment and
enforce environmental, health, safety and security mechanisms through
accountability at all levels, suitable policies, feedback and full compliance
by each employee and contractor to all policies we develop.
The Government has historically played a key role, and is expected to continue
to play a key role in regulating, reforming and restructuring the Indian oil
and natural gas industry. A major platform for shaping the industry has been
the award of assets by various rounds under the NELP. Our Block was awarded
before the formation of NELP and therefore places greater emphasis on our
Production Sharing Contract (PSC) in our dealings with Government in various
forms. To date the Block Management Committee created under our PSC and
including multiple Government agencies has assisted the development progress
we have made so far. The Field Development Plan for the area beyond SGL was
approved by Management Committee consisting representatives of DGH and
government created under PSC. The Production Sharing Contract has expired and
its renewal is currently pending Government approval; once approved, it will
continue to include cost recovery and a long-term gas sales contract will be
signed to enhance cash flow for debt servicing and protect lenders.
Corporate Governance
The Directors recognize the importance of sound corporate governance and have
chosen to apply the Quoted Companies Alliance ("QCA") Corporate Governance
Code and Guernsey regulations in so far as they are appropriate given the
Group's size and stage of development. The Group may take additional Corporate
Governance measures beyond QCA guidelines and Guernsey regulations as may be
appropriate considering the Group's operations from time to time.
The Group has not adopted the UK Corporate Governance Code ("the Code") and
has chosen to apply the QCA Corporate Governance Code for Small and Mid-Size
Quoted Companies which is in line with most growing AIM companies adopted
practices. The disclosure requirements under the code have been complied with
and the detailed report is available on the official website
(http://www.indusgas.com/ (http://www.indusgas.com/) ) of the Group.
Corporate Governance standards and procedures adopted by the Group are
regularly reviewed by the Chairman who has maintained dialogue and answered
questions of shareholders throughout the year. The Chairman has consulted the
Nomad on the objectives of Corporate Governance within the Group.
BOARD OF DIRECTORS
The Board is responsible for the proper management of the Group. The resumes
of the current board members are as outlined in the section 'Board of
Directors' on page no. 6.
Mr. Ajay Kalsi brings knowledge of the oil and gas industry and a range of
general business skills and continues to be an advisor to the Group. The other
Directors had formed a number of committees to assist in the governance of the
Group and these are detailed below.
All Directors have access to independent professional advice, at the Group's
expense, when required.
SUB-COMMITTEES
The Board had constituted the nomination and remuneration sub-committees,
which were then disbanded in March 2022 as a result of the Board's reduced
size. Given the Board's new directors appointed recently, nomination and
remuneration sub-committees may reform in future. Further, currently, all the
responsibilities of these sub committees are being carried out directly by the
Board in line with defined policies and processes.
SHARE DEALING
The Group has adopted a share dealing code (based on the Model Code) and the
Group takes all proper and reasonable steps to ensure compliance by Directors
and relevant employees.
THE CITY CODE ON TAKEOVERS AND MERGERS
Being a Channel Islands incorporated Group, the Group is subject to the UK
City Code on Takeovers and Mergers.
DISCLOSURE AND TRANSPARENCY RULES
As a Group incorporated in Guernsey, Shareholders are not obliged to disclose
their interests in the Group in the same way as shareholders of certain
companies incorporated in the UK. In particular, the relevant provisions of
chapter 5 of the Disclosure and Transparency Rules (DTR) do not apply. While
the Articles contain provisions requiring disclosure of voting rights in
Ordinary Shares, which are similar to the provisions of the DTR, this may not
always, ensure compliance with the requirements of Rule 17 of the AIM Rules.
Furthermore, the Articles may be amended in the future by a special resolution
of the Shareholders.
CONTROL BY SIGNIFICANT SHAREHOLDER
Gynia Holdings Limited, along with its wholly owned subsidiary Focus oil Inc.,
own a significant percentage of outstanding shares of the Group. As a
significant shareholder, Gynia could exercise significant influence over
certain corporate governance matters requiring shareholder approval, including
the election of directors and the approval of significant corporate
transactions and other transactions requiring a majority vote.
The Group, Strand Hanson Limited (Nomad and Broker), Gynia and Mr. Ajay Kalsi
have entered into a relationship agreement to regulate the arrangements
between them. The relationship agreement applies for as long as Gynia directly
or indirectly holds in excess of thirty per cent of the issued share capital
of the Group and the Group's shares remain admitted to trading on AIM. The
relationship agreement includes provisions to ensure that:
a) The Board and its committees are able to carry on their business
independently of the personal interests of Gynia;
b) The constitutional documents of the Group are not changed in such a way
which would be inconsistent with the relationship agreement.
c) In the event of a conflict of interest between Gynia and the Board, no
person who is connected with Gynia is appointed as a Non-Executive Director of
the Group and no existing Non-Executive Director is removed as a director of
the Group unless such an appointment or removal has been previously approved
by the nomination committee of the Board and that to the extent that any
previously approved by the nomination committees concerns the composition of
the Board which has been approved by the Board requiring the approval of the
shareholders of the Group then Gynia will vote its Ordinary Shares in favour;
and
d) The Shareholder puts certain restrictions in place to prevent
interference with the business of the Group.
INDEPENDENT AUDITOR'S REPORT
To the members of Indus Gas Limited
Opinion
We have audited the consolidated financial statements of Indus Gas Limited
(the "Company") and its subsidiaries (the "Group") for the year ended 31 March
2025, which comprise the Consolidated Statement of Financial Position, the
Consolidated Statement of Comprehensive Income, the Consolidated Statement of
Changes in Equity, the Consolidated Statement of Cash Flows for the year then
ended, and Notes to the consolidated financial statements, including a summary
of material accounting policy information.
In our opinion, the accompanied consolidated financial statements:
· give a true and fair view of the financial position of the Group
as at 31 March 2025, and of its financial performance and its cashflows for
the year then ended;
· are in accordance with IFRS Accounting Standards (IFRSs) as
adopted by the European Union (EU); and
· comply with the Companies (Guernsey) Law, 2008.
Basis for opinion
We conducted our audit in accordance with International Standards on Auditing
(ISAs) and applicable law. Our responsibilities under those standards are
further described in the 'Auditor's responsibilities for the audit of the
consolidated financial statements' section of our report. We are independent
of the Group in accordance with the International Ethics Standards Board for
Accountants' International Code of Ethics for Professional Accountants
(including International Independence Standards) (IESBA Code), together with
the ethical requirements that are relevant to our audit of the consolidated
financial statements in Guernsey, and we have fulfilled our other ethical
responsibilities in accordance with these requirements and the IESBA Code. We
believe that the audit evidence we have obtained is sufficient and appropriate
to provide a basis for our opinion.
Material Uncertainty related to going concern
We draw attention to Note 6.16 in the consolidated financial statements, which
explains that the Group's Production Sharing Contract (PSC) expired on 20
August 2024 and has not been extended as of the date of approval of the
consolidated financial statements. The Gas Sales and Purchase Agreement (GSPA)
with the Group's sole customer, Gas Authority of India Limited (GAIL), also
expired on 30 September 2024. The Group has entered into an interim term sheet
for gas sales, which is renewable every six months and currently extended
until 31 January 2026.
These events, along with other matters described in Note 6.16, indicate the
existence of a material uncertainty that may cast significant doubt on the
Group's ability to continue as a going concern.
Our opinion is not modified in respect of this matter.
Key audit matters
Key audit matters are those matters that, in our professional judgement, were
of most significance in our audit of the consolidated financial statements of
the current period. These matters were addressed in the context of our audit
of the financial statements as a whole, and in forming our opinion thereon,
and we do not provide a separate opinion on these matters. In addition to the
matter described in the Material Uncertainty Related to Going Concern section,
we have determined the matters described below to be key audit matters to be
communicated in our report.
The key audit matter How the matter was addressed in our audit
Impairment of production and development assets ("P&D assets") In responding to the key audit matter, we performed the following audit
procedures:
We identified the impairment of P&D assets as one of the most significant
assessed risks of material misstatement due to error. · We compared the carrying value of assets to management's
assessment of the recoverable amount to assess whether the carrying value is
At 31 March 2025, the Group held P&D assets of US$776,139,979 (31March not in excess of the recoverable amount.
2024: US$ 1,280,828,703).
· We agreed the recoverable amount to management's future cash flow
The recoverability of property and development (P&D) assets depends on the model and evaluated:
future success of exploration and development activities. In accordance with
IAS 16 "Property, Plant and Equipment" and IAS 36 "Impairment of Assets", an o Future cash flow estimates, including price, volume, and cost estimates
impairment assessment is required. supported by documentation.
Based on our professional judgement, the carrying value of P&D assets o Sensitivity analysis of key inputs (including price, discount rate,
totalling US$771,085,744 is supported by projected future cash flows. The operating cost etc).
Group capitalised these assets in line with IFRS 6 and IAS 16 recognition
criteria. Approvals have been obtained from the Directorate General of o The appropriateness of the cash generating unit ("CGU") definitions and
Hydrocarbons for reserves in the SSG and SSF fields, and the Management impairment methodology under IFRSs as adopted by the EU, including related
Committee has endorsed the revised Field Development Plan for the SGL area. disclosures.
Given the long-lived nature of these assets, key assumptions in management's o Methodology used to assess the carrying value of P&D assets at the CGU
cash flow forecasts include sales volumes and gas price outlook. As at 31 level for compliance and consistency.
March 2025, the Group assessed the carrying value of its gas production assets
in Block RJ-ON/6 under IAS 36, triggered by factors such as PSC and GSPA o Evaluated the work of management's appointed valuer for competence,
expiry, declining production, reservoir challenges, and ongoing arbitration capability and objectivity.
with GAIL (India) Limited.
o Engaged an independent external valuer and consulted internal specialists
Impairment of P&D assets is a key audit matter due to the significant to challenge and validate key assumptions.
judgement involved in estimating future cash flows and determining the
appropriate discount rate. Our results
Based on our procedures we have not identified any material misstatements in
relation to the impairment of production and development costs.
Relevant disclosures in the Annual Report and Accounts 2024-25
· Consolidated Financial statements: Note 6.7, Impairment testing
for exploration and evaluation assets and property, plant and equipment.
· Consolidated Financial Statements: Note 7, Property, plant and
equipment.
Other information in the Annual Report
The directors are responsible for the other information. The other information
comprises the information included in the Annual Report and Audited
consolidated financial statements, but does not include the consolidated
financial statements and our auditor's report thereon.
Our opinion on the consolidated financial statements does not cover the other
information and, except to the extent otherwise explicitly stated in our
report, we do not express any form of assurance conclusion thereon.
In connection with our audit of the consolidated financial statements, our
responsibility is to read the other information and, in doing so, consider
whether the other information is materially inconsistent with the consolidated
financial statements or our knowledge obtained in the audit or otherwise
appears to be materially misstated. If, based on the work we have performed,
we conclude that there is a material misstatement of this other information,
we are required to report that fact. We have nothing to report in this regard.
Responsibilities of the directors for the consolidated financial statements
As explained more fully in the Statement of Directors' Responsibilities set
out on page 10, the Directors are responsible for the preparation of the
consolidated financial statements which give a true and fair view in
accordance with IFRS Accounting Standards as adopted by the EU, and for such
internal control as the Directors determine is necessary to enable the
preparation of consolidated financial statements that are free from material
misstatement, whether due to fraud or error.
In preparing the consolidated financial statements, the Directors are
responsible for assessing the Company's ability to continue as a going
concern, disclosing, as applicable, matters related to going concern and using
the going concern basis of accounting unless the Directors either intend to
liquidate the Group or to cease operations, or have no realistic alternative
but to do so.
Auditor's responsibilities for the audit of the consolidated financial statements
Our objectives are to obtain reasonable assurance about whether the
consolidated financial statements as a whole are free from material
misstatement, whether due to fraud or error, and to issue an auditor's report
that includes our opinion. Reasonable assurance is a high level of assurance,
but is not a guarantee that an audit conducted in accordance with ISAs will
always detect a material misstatement when it exists. Misstatements can arise
from fraud or error and are considered material if, individually or in the
aggregate, they could reasonably be expected to influence the economic
decisions of users taken on the basis of these consolidated financial
statements.
As part of an audit in accordance with ISAs, we exercise professional judgment
and maintain professional scepticism throughout the audit. We also:
· Identify and assess the risks of material misstatement of the
consolidated financial statements, whether due to fraud or error, design and
perform audit procedures responsive to those risks, and obtain audit evidence
that is sufficient and appropriate to provide a basis for our opinion. The
risk of not detecting a material misstatement resulting from fraud is higher
than for one resulting from error, as fraud may involve collusion, forgery,
intentional omissions, misrepresentations, or the override of internal
control.
· Obtain an understanding of internal control relevant to the audit in
order to design audit procedures that are appropriate in the circumstances,
but not for the purpose of expressing an opinion on the effectiveness of the
Company's internal control.
· Evaluate the appropriateness of accounting policies used and the
reasonableness of accounting estimates and related disclosures made by the
Directors.
· Conclude on the appropriateness of the Directors' use of the going
concern basis of accounting and, based on the audit evidence obtained, whether
a material uncertainty exists related to events or conditions that may cast
significant doubt on Company's ability to continue as a going concern. If we
conclude that a material uncertainty exists, we are required to draw attention
in our auditor's report to the related disclosures in the consolidated
financial statements or, if such disclosures are inadequate, to modify our
opinion. Our conclusions are based on the audit evidence obtained up to the
date of our auditor's report. However, future events or conditions may cause
the Company to cease to continue as a going concern.
· Obtain sufficient appropriate audit evidence regarding the financial
information of the entities or business activities within the Group to express
an opinion on the consolidated financial statements. We are responsible for
the direction, supervision and performance of the Group audit. We remain
solely responsible for our audit opinion.
· Evaluate the overall presentation, structure and content of the
consolidated financial statements, including the disclosures, and whether the
consolidated financial statements represent the underlying transactions and
events in a manner that achieves fair presentation.
We communicate with the directors regarding, among other matters, the planned
scope and timing of the audit and significant audit findings, including any
significant deficiencies in internal control that we identify during our
audit.
We also provide the directors with a statement that we have complied with
relevant ethical requirements regarding independence, and to communicate with
them all relationships and other matters that may reasonably be thought to
bear on our independence, and where applicable, actions taken to eliminate
threats or safeguards applied.
From the matters communicated with the directors, we determine those matters
that were of most significance in the audit of the consolidated financial
statements of the current period and are therefore the key audit matters. We
describe these matters in our auditor's report unless law or regulation
precludes public disclosure about the matter or when, in extremely rare
circumstances, we determine that a matter should not be communicated in our
report because the adverse consequences of doing so would reasonably be
expected to outweigh the public interest benefits of such communication.
The engagement partner on the audit resulting in this independent auditor's
report is Michael Carpenter.
Use of our report
This report is made solely to the Company's members, as a body, in accordance
with section 262 of the Companies (Guernsey) Law, 2008. Our audit work has
been undertaken so that we might state to the Company's members those matters
we are required to state to them in an auditor's report and for no other
purpose. To the fullest extent permitted by law, we do not accept or assume
responsibility to anyone other than the Company and the Company's members as a
body, for our audit work, for this report, or for the opinions we have formed.
Matters on which we are required to report by exception
We have nothing to report in respect of the following matters in relation to
which the Companies (Guernsey) Law, 2008 requires us to report to you if, in
our opinion:
· proper accounting records have not been kept by the Company; or
· the Group's consolidated financial statements are not in
agreement with the accounting records; or
· we have not obtained all the information and explanations, which
to the best of our knowledge and belief, are necessary for the purposes of our
audit.
Grant Thornton Limited
Chartered Accountants
St Peter Port
Guernsey
Date: 29 September 2025
Consolidated Statement of Financial Position
(All amounts in United States Dollars, unless otherwise stated)
Note 31 March 2025 31 March 2024
ASSETS
Non-current assets
Property, plant and equipment 7 776,139,979 1,291,623,066
333,262 763,236
8,957 9,132
Tax assets
Other assets
Total non-current assets 776,482,198 1,292,395,434
Current assets
Inventories 10 6,898,623 8,944,689
Trade and other receivables 11 638,220 621,664
Prepayment and other assets due from a related party 16 109,239,970 107,305,566
Cash and cash equivalents 12 240,220 2,069,244
Total current assets 117,017,033 118,941,163
Total assets
893,499,231 1,411,336,597
LIABILITIES AND EQUITY
Shareholders' equity
Share capital 13 3,619,443 3,619,443
Additional paid-in capital 13 46,733,689 46,733,689
Currency translation reserve 13 (9,313,782) (9,313,782)
Merger reserve 13 19,570,288 19,570,288
Retained (losses)/earnings 13 (54,557,477) 303,018,938
Total shareholders' equity 6,052,161 363,628,576
Liabilities
Non-current liabilities
Long term debt, excluding current portion 14 159,581,721 159,689,118
Provision for decommissioning 15 1,899,606 1,881,606
Deferred tax liabilities (net) 8 - 160,142,858
Payable to related parties, excluding current portion 16 - 678,410,347
Total non-current liabilities 161,481,327 1,000,123,929
Current liabilities
Current portion of long-term debt 14 4,505,626 20,575,321
Current portion payable to related parties 16 709,604,109 12,656
Trade and other payables 17 1,602,524 1,525,980
Current tax liabilities 9 10,253,484 -
Deferred Revenue 18 - 25,470,135
Total current liabilities 725,965,743 47,584,092
Total liabilities 887,447,070 1,047,708,021
Total equity and liabilities 893,499,231 1,411,336,597
(The accompanying notes are an integral part of these consolidated financial
statements)
These consolidated financial statements were approved and authorized for issue
by the board on 29 September 2025 and were signed on its behalf by:
JONATHAN KEELING
Chairman
Consolidated Statement of Comprehensive Income
(All amounts in United States Dollars, unless otherwise stated)
Note Year ended Year ended
31 March 2025 31 March 2024
Revenues 18 29,651,641 42,930,441
Cost of sales (2,400,801) (5,462,071)
Gross profit 27,250,840 37,468,370
Cost and expenses
Administrative expenses 868,541 912,835
Operating profit 26,382,299 36,555,535
Foreign currency exchange gain, net 20 2,963 (434,837)
Profit before tax 26,385,262 36,120,698
Income taxes
Income tax expense 9 (10,253,484) - (15,749,907)
Tax for earlier years 9 - (186,266)
Impairment
Impairment of Property Plant and Equipment's (533,851,051) -
Deferred tax income/expense) 160,142,858 -
(357,576,415) 20,184,525
(Loss)/Profit for the year (attributable to the shareholders of the Group)
Total comprehensive (loss)/income for the year (attributable to the (357,576,415) 20,184,525
shareholders of the Group)
Earnings per share 21
Basic (1.95) 0.11
Diluted (1.95) 0.11
(The accompanying notes are an integral part of these consolidated financial
statements)
Consolidated Statement of Changes in Equity
(All amounts in United States Dollars, unless otherwise stated)
Common stock Additional paid in capital Currency translation reserve Merger reserve Retained earnings Total shareholders' equity
No. of shares Amount
Balance as at 1 April 2024 182,973,924 3,619,443 46,733,689 (9,313,782) 19,570,288 303,018,938 363,628,576
Total comprehensive loss for the year - - - - - (357,576,415) (357,576,415)
Balance as at 31 March 2025 182,973,924 3,619,443 46,733,689 (9,313,782) 19,570,288 (54,557,477) 6,052,161
(The accompanying notes are an integral part of these consolidated financial
statements)
Consolidated Statement of Cash Flows
(All amounts in United States Dollars, unless otherwise stated)
Year ended ( ) Year ended
31 March 2025 31 March 2024
Cash flow from operating activities ( )
Profit before tax 26,385,262 ( ) 36,120,698
Adjustments ( )
Unrealized exchange (loss)/gain (2,963) ( ) 434,837
Depreciation 1,203,224 ( ) 4,821,537
Changes in operating assets and liabilities ( )
Inventories 2,046,066 ( ) 987,358
Trade receivables (16,556) ( ) 6,019,121
Deferred Revenue (25,470,135) ( ) (4,841,613)
Payable to related party-operating activities 2,551,924 ( ) 5,551,919
Provisions for decommissioning 18,000 ( ) (13,190)
Accrued expenses and other liabilities 107,653 ( ) (831,032)
Cash generated from operations 6,822,475 ( ) 48,249,635
Income taxes received 429,972 ( ) 191,826
Net cash generated from operating activities 7,252,447 ( ) 48,441,461
( )
Cash flow from investing activities
Purchase of property, plant and equipment (10,591,872) (22,034,131)
Net cash used in investing activities (10,591,872) ( ) (22,034,131)
( )
Cash flow from financing activities ( )
(15,984,000) (23,652,000)
Repayment of long-term debt from banks
Proceeds from loans by related parties 31,625,000 ( ) 9,877,100
Repayment of loans by related parties (475,000) ( ) (6,500,000)
Payment of interest (13,658,561) ( ) (15,393,864)
Net cash generated from/ (used in) financing activities 1,507,439 ( ) (35,668,764)
Net decrease in cash and cash equivalents (1,831,986) ( ) (9,261,434)
Cash and cash equivalents at the beginning of the year 2,069,244 ( ) 11,765,515
Effects of exchange differences on cash and cash equivalents 2,962 (434,837)
Cash and cash equivalents at the end of the year 240,220 ( ) 2,069,244
(The accompanying notes are an integral part of these consolidated financial
statements)
Notes to Consolidated Financial Statements
(All amounts in United States Dollars, unless otherwise stated)
1. INTRODUCTION
Indus Gas Limited ("Indus Gas" or "the Company") was incorporated in the
Island of Guernsey on 4 March 2008 pursuant to an Act of the Royal Court of
the Island of Guernsey. The Company was set up to act as the holding Company
of iServices Investments Limited. ("iServices") and Newbury Oil Co. Limited
("Newbury"). iServices and Newbury are companies incorporated in Mauritius and
Cyprus, respectively. iServices was incorporated on 18 June 2003 and Newbury
was incorporated on 17 February 2005. The Company was listed on the
Alternative Investment Market (AIM) of the London Stock Exchange on 6 June
2008. Indus Gas through its wholly owned subsidiaries iServices and Newbury
(hereinafter collectively referred to as "the Group") are engaged in the
business of oil and gas exploration, development and production.
Focus Energy Limited ("Focus"), an entity incorporated in India, entered into
a Production Sharing Contract ("PSC") with the Government of India ("GOI") and
Oil and Natural Gas Corporation Limited ("ONGC") on 30 June 1998 for petroleum
exploration and development concession in India known as RJ-ON/06 ("the
Block"). Focus is the Operator of the Block. On 13 January 2006, iServices and
Newbury entered into an interest sharing agreement with Focus and obtained a
65 per cent and 25 per cent share respectively in the Block. The balance of 10
per cent of participating interest is owned by Focus. The participating
interest explained above is subject to any option exercised by ONGC in respect
of individual fields (already exercised for all the wells in SGL field as
further explained in note 3).
2. GENERAL INFORMATION
The consolidated financial statements of the Group have been prepared in
accordance with IFRS Accounting Standards ('IFRS') as adopted by the European
Union ('EU'). The consolidated financial statements have been prepared on a
going concern basis (refer to note 6.16) and are presented in United States
Dollar (US$). The functional currency of the Group as well as its subsidiaries
is US$.
3. JOINTLY CONTROLLED ASSETS
As explained above, the Group through its subsidiaries-iServices and Newbury
has an "Interest sharing arrangement" with Focus in the block, which under
IFRS 11 Joint Arrangements, is classified as a 'Joint operation'. All rights
and obligations in respect of exploration, development and production of oil
and gas resources under the 'Interest sharing agreement' are shared between
Focus, iServices and Newbury in the ratio of 10 per cent, 65 per cent and 25
per cent respectively.
Under the PSC, the GOI, through ONGC has an option to acquire a 30 per cent
participating interest in any discovered field, upon such successful discovery
of oil or gas reserves, which has been declared as commercially feasible to
develop.
The block is divided into 3 fields - SGL, SSF and SSG.
The SGL field received its declaration of commercial discovery on 21 January
2008. Subsequent to the declaration of commercial discovery in SGL field, ONGC
exercised the option to acquire a 30 per cent participating interest in the
discovered fields on 6 June 2008. The exercise of this option reduced the
interest of the existing partners proportionately.
However, on exercise of this option, ONGC is liable to pay its share of 30 per
cent of the SGL field development costs and production costs incurred after 21
January 2008 and are entitled to a 30 per cent share in the production of gas
subject to recovery of contract costs as explained below.
The allocation of the production from the field to each participant in any
year is determined on the basis of the respective proportion of each
participant's cumulative unrecovered contract costs as at the end of the
previous year or where there is no unrecovered contract cost at the end of
previous year on the basis of participating interest of each such participant
in the field.
On the basis of the above, gas production for the year ended 31 March 2025 is
shared between Focus, iServices and Newbury in the ratio of 10 percent, 65
percent and 25 percent, respectively. ONGC will not be entitled to any
participating interest in the production until the full exploration and
development cost and production cost is recovered by other participants.
The aggregate amounts relating to jointly controlled assets, liabilities,
expenses and commitments related thereto that have been included in the
consolidated financial statements are as follows:
31 March 2025 31 March 2024
Non-current assets 776,139,979 1,291,623,477
Current 116,250,255
assets
116,138,593
Non-current 1,899,607 1,881,607
liabilities
Expenses (net of finance income) 2,551,750 5,551,919
Further, the SSF and SSG field also received its declaration of commerciality
on 24th November 2014. Subsequent to the declaration of commerciality for SSF
and SSG discovery, ONGC did not exercise the option to acquire 30 percent in
respect of SSG and SSF field. The participating interest in SSG and SSF field
between Focus, iServices and Newbury will remain in ratio of 10 percent, 65
percent and 25 percent respectively for exploration, evaluation and
development cost, and production revenue for SSG and SSF in the block.
4. NEW AND AMENDED STANDARDS ADOPTED BY THE GROUP
These following amendments to various IFRS Accounting Standards are
mandatorily effective for reporting periods beginning on or after 1 January
2024:
a. Classification of Liabilities as Current or Non-current (Amendments to
IAS 1)
b. Lease Liability in a Sale and Leaseback (Amendments to IFRS 16)
c. Supplier Finance Arrangements (Amendments to IAS 7 and IFRS 7)
d. Non-current Liabilities with Covenants (Amendments to IAS 1)
These amendments do not have a significant impact on the consolidated
Financial Statements and therefore the disclosures have not been made.
5. STANDARDS AND INTERPRETATIONS ISSUED BUT NOT EFFECTIVE AND YET TO BE
APPLIED BY THE GROUP
A number of new and amended accounting standards and interpretations have been
published that are not mandatory for the Group's accounts ended 31 March 2025
nor have they been early adopted. These standards and interpretations are not
expected to have a material impact on the Group's consolidated financial
statements. Even though IFRS 18 will not have any effect on the recognition
and measurement of items in the consolidated financial statements, it is
expected to have a significant effect on the presentation and disclosure of
certain items.:
i. Lack of Exchangeability (Amendments to IAS 21)
ii. Amendments to the Classification and Measurement of Financial
Instruments (Amendments to IFRS 9 and IFRS 7)
iii. IFRS 18 - Presentation and Disclosure in Financial Statements
iv. IFRS 19 - Subsidiaries without Public Accountability: Disclosures
6. SUMMARY OF MATERIAL ACCOUNTING POLICIES
The consolidated financial statements have been prepared on a historical
basis, except where specified below. A summary of the material accounting
policies applied in the preparation of the accompanying consolidated financial
statements are detailed below.
6.1. BASIS OF CONSOLIDATION
The consolidated financial statements include the financial statements of the
parent company and all of its subsidiary undertakings drawn up to 31 March
2025. The Group consolidates entities which it controls. Control exists when
the parent has power over the entity, is exposed, or has rights, to variable
returns from its involvement with the entity and has the ability to affect
those returns by using its power over the entity. Power is demonstrated
through existing rights that give the ability to direct relevant activities,
those which significantly affect the entity's returns.
The Group recognises in relation to its interest in a joint operation:
a. its assets, including its share of any assets held jointly;
b. its liabilities, including its share of any liabilities
incurred jointly;
c. its revenue from the sale of its share of the output
arising from the joint operation;
d. its share of the revenue from the sale of the output by the
joint operation; and
e. its expenses, including its share of any expenses incurred
jointly.
Intra-Group balances and transactions, and any unrealised gains and losses
arising from intra-Group transactions are eliminated in preparing the
consolidated financial statements. Amounts reported in the financial
statements of subsidiaries have been adjusted where necessary to ensure
consistency with the accounting policies adopted by the Group.
Profit or losses of subsidiaries acquired or disposed of during the year are
recognised from the date of control of acquisition, or up to the effective
date of disposal, as applicable.
6.2. SIGNIFICANT ACCOUNTING JUDGEMENTS AND ESTIMATES
In preparing consolidated financial statements, the Group's management is
required to make judgments, estimates and assumptions that affect the reported
amounts of assets and liabilities and the disclosure of contingent assets and
liabilities at the date of the financial statement and the reported amounts of
revenues and expenses during the reporting period. Although these estimates
are based on management's best knowledge of current events and actions, actual
results may ultimately differ from those estimates. The management's estimates
for the useful life and residual value of tangible assets, impairment of
tangible assets and recognition of provision for decommissioning represent
certain particularly sensitive estimates. The estimates and underlying
assumptions are reviewed on an on-going basis. Revisions to accounting
estimates are recognized 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 current and future periods. Information
about significant judgments, estimates and assumptions that have the most
significant effect on recognition and measurement of assets, liabilities,
revenues and expenses is provided in note 26.
6.3. FOREIGN CURRENCIES
The consolidated financial statements have been presented in US$ which is the
functional currency of the Company and the group entities.
Foreign currency transactions are translated into the functional currency of
the respective Group entities, using the exchange rates prevailing at the
dates of the transactions (spot exchange rate).
Functional currency is the currency of the primary economic environment in
which the entity operates.
Monetary assets and liabilities denominated in foreign currencies are
translated at the functional currency spot rates of exchange at the reporting
date. Differences arising on settlement or translation of monetary items and
other foreign currency transactions are recognized in consolidated statement
of comprehensive income.
Non-monetary items measured at historical cost are recorded in the functional
currency of the entity using the exchange rates at the date of the
transaction.
6.4. REVENUE RECOGNITION
In accordance with IFRS 15, Revenue from contracts with customers is
recognised when or as the Company satisfies a performance obligation by
transferring control of promised goods to a customer at an amount that
reflects the consideration to which the Company expects to be entitled in
exchange for the sale of products, net of taxes on sales, estimated rebates
and other similar allowances.
Sale of gas
The contracts with customers establish a single performance obligation in
relation to supply of natural gas. The transfer of control of natural gas
coincides with title passing to the customer and the customer taking physical
possession. The whole of the transaction price of the contract is allocated to
supply of natural gas and the revenue has been recognised on point in time
basis when the quantities of natural gas are supplied to the customers.
The Group has only one contractual arrangement for sale of gas to Gas
Authority of India Limited (GAIL), wherein the revenue gets recognised on the
basis of delivery i.e. point in time revenue recognition. Further, there are
no other performance obligations which the company is liable to perform. As
per the contract signed with customer, entity is eligible to recover the
amount from customer within 15 days of raising invoice.
The Group updates its estimated transaction price at each reporting period, to
represent faithfully the circumstances present at the end of the reporting
period and the changes in circumstances during the reporting period including
penalties, discounts and damages etc.
Take or pay:
Any payment received on account of lesser gas volume lifted by the customer
against the "annual contracted volume" for which an obligation exists to
make-up such differential gas in subsequent periods is recognised as Contract
Liabilities in the year of receipt. Revenue in respect of take or pay
obligation is recognised when such gas is actually supplied or when the
customer's right to make up is expired, whichever is earlier. For other
contracts, where the Group does not have any obligation to make up such gas in
subsequent period is directly recognised as revenue.
6.5. PROPERTY, PLANT AND EQUIPMENT
Property, plant and equipment comprise development assets and other
properties, plant and equipment used in the gas fields and for administrative
purposes. These assets are stated at cost plus decommissioning cost less
accumulated depreciation and any accumulated impairment losses.
Development assets are accumulated on a field-by-field basis and comprise
costs of developing the commercially feasible reserve, expenditure on the
construction, installation or completion of infrastructure facilities such as
platforms, pipelines and other costs of bringing such reserves into
production. It also includes the exploration and evaluation costs incurred in
discovering the commercially feasible reserve, which have been transferred
from the exploration and evaluation assets as per the policy mentioned in note
6.6. As consistent with the full cost method, all exploration and evaluation
expenditure incurred up to the date of the commercial discovery have been
classified under development assets of that field.
The carrying values of property, plant and equipment are reviewed for
impairment when events or changes in circumstances indicate that the carrying
values may not be recoverable.
An item of property, plant and equipment is derecognized upon disposal or when
no future economic benefits are expected from its use or disposal. Any gain or
loss arising on de-recognition of the asset (calculated as the difference
between the net disposal proceeds and the carrying amount of the asset) is
included in the consolidated statement of comprehensive income of the year in
which the asset is derecognized. However, where the asset is being consumed in
developing exploration and evaluation assets, such gain or loss is recognized
as part of the cost of the asset.
The asset's residual values, useful lives and depreciation methods are
reviewed, and adjusted if appropriate, at each period end. No depreciation is
charged on development assets until production commences.
Depreciation on property, plant and equipment is provided at rates estimated
by the management. Depreciation is computed using the straight-line method of
depreciation, whereby each asset is written down to its estimated residual
value evenly over its expected useful life. The useful lives estimated by
the management are as follows:
Extended well test equipment 20 years
Bunk houses 5 years
Vehicles 5 years
Other assets
Furniture and fixture 5 years
Buildings 10 years
Computer equipment 3 years
Other equipment 5 years
Land acquired is recognized at cost and no depreciation is charged as it has
an unlimited useful life.
Production assets are depreciated from the date of commencement of production,
on a field-by-field basis with reference to the unit of production method for
the commercially probable and proven reserves in the particular field.
Advances paid for the acquisition/ construction of property, plant and
equipment which are outstanding at the end of the reporting period and the
cost of property, plant and equipment under construction before such date are
disclosed as 'Capital work-in-progress'.
6.6. EXPLORATION AND EVALUATION ASSETS
The Group adopts the full cost method of accounting for its oil and gas
interests, having regard to the requirements of IFRS 6: Exploration for and
Evaluation of Mineral Resources. Under the full cost method of accounting, all
costs of exploring for and evaluating oil and gas properties, whether
productive or not are accumulated and capitalized by reference to appropriate
cost pools. Such cost pools are based on geographic areas and are not larger
than a segment. The Group currently has one cost pool being an area of land
located in Rajasthan, India.
Exploration and evaluation costs may include costs of license acquisition,
directly attributable exploration costs such as technical services and
studies, seismic data acquisition and processing, exploration drilling and
testing, technical feasibility, commercial viability costs, finance costs to
the extent they are directly attributable to financing these activities and an
allocation of administrative and salary costs as determined by management. All
costs incurred prior to the award of an exploration license are written off as
a loss in the year incurred.
Exploration and evaluation costs are classified as tangible asset according to
the nature of the assets acquired and the classification is applied
consistently. Tangible exploration and evaluation assets are recognized and
measured in accordance with the accounting policy on property, plant and
equipment. To the extent that such a tangible asset is consumed in developing
exploration and evaluation asset, the amount reflecting that consumption is
recorded as part of the cost of the asset.
Exploration and evaluation assets are not amortized prior to the conclusion of
appraisal activities. Where technical feasibility and commercial viability is
demonstrated, the carrying value of the relevant exploration and evaluation
asset is reclassified as a development and production asset and tested for
impairment on the date of reclassification. Impairment loss, if any, is
recognized.
The group has completed exploration and evaluation phase in 2017 when field
development plan has been approved by Directorate General of Hydrocarbons
('DGH') i.e., technical feasibility and commercial viability were
demonstrable. Therefore, any cost incurred thereafter on development
activities is capitalized directly to development assets.
6.7. IMPAIRMENT TESTING FOR EXPLORATION AND EVALUATION ASSETS AND
PROPERTY, PLANT AND EQUIPMENT
An impairment loss is recognized for the amount by which an asset's
cash-generating unit's carrying amount exceeds its recoverable amount. The
recoverable amount is the higher of fair value, reflecting market conditions
less costs to sell, and value in use based on an internal discounted cash flow
evaluation.
Where there are indicators that an exploration asset may be impaired, the
exploration and evaluation assets are grouped with all development/producing
assets belonging to the same geographic segment to form the Cash Generating
Unit (CGU) for impairment testing. Where there are indicators that an item of
property, plant and equipment asset is impaired, assets are grouped at the
lowest levels for which there are separately identifiable cash flows to form
the CGU. The combined cost of the CGU is compared against the CGU's
recoverable amount and any resulting impairment loss is written off in the
profit or loss of the year. During the year, the company has recognized
impairment of assets.
An assessment is made at each reporting date as to whether there is any
indication that previously recognized impairment losses may no longer exist or
may have decreased. If such indication exists, the Group estimates the asset's
or CGU's recoverable amount. A previously recognized impairment loss is
reversed only if there has been a change in the assumptions used to determine
the asset's recoverable amount since the last impairment loss was recognized.
The reversal is limited so that the carrying amount of the asset does not
exceed its recoverable amount, nor exceed the carrying amount that would have
been determined, net of depreciation, had no impairment loss been recognized
for the asset in prior years. Such reversal is recognized in profit or loss
unless the asset is carried at a re-valued amount, in which case the reversal
is treated as a revaluation increase.
6.8. FINANCIAL ASSETS
Financial Instruments
Financial assets and financial liabilities are recognized when the Group
becomes a party to the contractual provisions of the financial instrument.
Financial assets are derecognized when the contractual rights to the cash
flows from the financial asset expire, or when the financial asset and all
substantial risks and rewards are transferred. A financial liability is
derecognized when it is extinguished, discharged, cancelled or expires.
Financial assets and financial liabilities are measured initially at fair
value plus transactions costs, except for financial assets and financial
liabilities carried at fair value through profit or loss, which are measured
initially at fair value. Trade receivables that do not contain a significant
financing component are measured at the transaction price. The value of
interest free financial assets and financial liabilities with short term
maturities are not discounted at initial recognition if the impact is not
material. Financial assets and financial liabilities are measured subsequently
as described below.
Recognition of Financial Asset
On initial recognition, a financial asset is classified as measured at
- Amortized cost;
- Fair value through other comprehensive income (FVOCI) - debt investment;
- Fair value through other comprehensive income (FVOCI) - equity investment;
or
- Fair value through profit and loss (FVTPL)
Financial assets are not reclassified subsequent to their initial recognition,
except if and in the period the Group changes its business model for managing
financial assets.
A financial asset is measured at amortized cost if it meets both of the
following conditions and is not designated as at FVTPL:
· The asset is held within a business model whose objective is to hold
assets to collect contractual cash flows; and the contractual terms of the
financial asset give rise on specified dates to cash flows that are solely
payments of principal and interest on the principal amount outstanding.
· The category determines subsequent measurement and whether any
resulting income and expense is recognized in consolidated statement of
comprehensive income.
After initial recognition, financials assets at amortized cost are measured at
amortized cost using the effective interest method.
Impairment of financial assets
IFRS 9's impairment requirements use more forward-looking information to
recognise expected credit losses - the 'expected credit loss (ECL) model'. The
Group considers a broader range of information when assessing credit risk and
measuring expected credit losses, including past events, current conditions,
reasonable and supportable forecasts that affect the expected collectability
of the future cash flows of the instrument.
In applying this forward-looking approach, a distinction is made between:
· financial instruments that have not deteriorated significantly in
credit quality since initial recognition or that have low credit risk and
· financial instruments that have deteriorated significantly in credit
quality since initial recognition and whose credit risk is not low.
· financial assets that have objective evidence of impairment at the
reporting date.
'12-month expected credit losses' are recognised for the first category while
'lifetime expected credit losses' are recognised for the second category.
The impairment methodology applied depends on whether there has been a
significant increase in credit risk. For trade receivables only, the Group
applies the simplified approach required by IFRS 9, which requires expected
lifetime losses to be recognised from initial recognition of the receivables.
6.9. FINANCIAL LIABILITIES
The Group's financial liabilities include borrowings, trade payables and other
payables which are classified as financial liabilities recognized at amortized
cost. Financial liabilities are measured subsequently at amortized cost using
the effective interest method except for financial liabilities at fair value
through profit or loss ("FVTPL"), that are carried subsequently at fair value
with gains or losses recognized in profit or loss in consolidated statement of
comprehensive income.
6.10. INVENTORIES
Inventories are measured at the lower of cost and net realizable value.
Inventories of drilling stores and spares are accounted for at cost
including taxes, duties and freight. The cost of all inventories other than
drilling bits is computed on the basis of the first in first out method. The
cost for drilling bits is computed based on specific identification method.
6.11. ACCOUNTING FOR INCOME TAXES
Income tax assets and/or liabilities comprise those obligations to, or claims
from, fiscal authorities relating to the current or prior reporting period
that are unrecovered/unpaid at the date of the statement of financial
position. They are calculated according to the tax rates and tax laws
applicable to the fiscal periods to which they relate, based on the taxable
profit for the year. All changes to current tax assets or liabilities are
recognized as a component of tax expense in consolidated statement of
comprehensive income.
Deferred income taxes are calculated using the balance sheet method on
temporary differences. This involves the comparison of the carrying amounts
of assets and liabilities in the financial statements with their tax bases.
The cost incurred on each field is claimed as deduction from the year of
commercial production. Deferred tax is, however, neither provided on the
initial recognition of goodwill, nor on the initial recognition of an asset or
liability unless the related transaction is a business combination or affects
tax or accounting profit. Tax losses available to be carried forward as well
as other income tax credits to the Group are assessed for recognition as
deferred tax assets.
Deferred tax liabilities are always provided for in full. Deferred tax assets
are recognized to the extent that it is probable that they will be offset
against future taxable income. Deferred tax assets and liabilities are
calculated, without discounting, at tax rates and laws that are expected to
apply to their respective period of realization, provided they are enacted or
substantively enacted at the date of the statement of financial position.
Changes in deferred tax assets or liabilities are recognized as a component of
tax expense in profit or loss of the year, except where they relate to items
that are charged or credited directly to other comprehensive income or equity
in which case the related deferred tax is also charged or credited directly to
other comprehensive income or equity.
Deferred tax assets and liabilities are offset when there is a legally
enforceable right to offset current tax assets and liabilities and when the
deferred tax balances relate to the same taxation authority.
6.12. BORROWING COSTS
Any interest payable on funds borrowed for the purpose of obtaining qualifying
assets, which are assets that necessarily take a substantial period of time to
get ready for their intended use or sale, is capitalized as a cost of that
asset until such time as the assets are substantially ready for their intended
use or sale. While the Group has not made any specific borrowings for
construction of a qualifying asset, they have capitalized certain borrowing
costs on account of general borrowings at an average rate of borrowings for
the Group in terms of IAS 23 'Borrowing Costs'.
Any associated interest charge from funds borrowed principally to address a
short-term cash flow shortfall during the suspension of development activities
is expensed in the period. Transaction costs incurred towards an unutilized
debt facility is treated as prepayments to be adjusted against the carrying
value of debt as and when drawn.
6.13. CASH AND CASH EQUIVALENTS
Cash and cash equivalents include cash in hand, at bank in demand deposits and
deposit with maturities of 3 months or less from inception, which are readily
convertible to known amounts of cash. These assets are subject to an
insignificant risk of change in value.
6.14. OTHER PROVISIONS AND CONTINGENT LIABILITIES
Provisions are recognized when the Group has a present obligation (legal or
constructive) as a result of a past event. It is probable that an outflow of
resources embodying economic benefits will be required to settle the
obligation and a reliable estimate can be made of the amount of the
obligation.
Where the Group expects some or all of provision to be reimbursed, for example
under an insurance contract, the reimbursement is recognized as a separate
asset but only when the reimbursement is virtually certain. The expense
relating to any provision net of any reimbursement is recognized in profit or
loss of the year. To the extent such expense is incurred for construction or
development of any asset, it is included in the cost of that asset. If the
effect of the time value of money is material, provisions are determined by
discounting the expected future cash flows at a pre-tax rate that reflects
current market assessments of the time value of money and, where appropriate,
the risks specific to the liability. Where discounting is used, the increase
in the provision due to the passage of time is recognized as other finance
expenses.
Provisions include decommissioning provisions representing management's best
estimate of the Group's liability for restoring the sites of drilled wells to
their original status. Provision for decommissioning is recognized at the
present value of the estimated future expenditure when the Group has an
obligation and a reliable estimate can be made, with a corresponding addition
to property, plant and equipment which is subsequently depreciated as part of
the asset.
Commitments and contingent liabilities are not recognized in the financial
statements. They are disclosed unless the possibility of an outflow of
resources embodying economic benefits is remote.
A contingent asset is not recognized but disclosed in the financial statements
when an inflow of economic benefits is probable but when it is virtually
certain than the asset is recognized in the financial statements.
In those cases, where the possible outflow of economic resources a result of
present obligations is considered improbable or remote, or the amount to be
provided for cannot be measured reliably, no liability is recognized in the
statement of financial position and no disclosure is made.
6.15. SEGMENT REPORTING
Operating segments are identified on the basis of internal reports about
components of the Group that are regularly reviewed by the Chief Operating
Decision Maker in order to allocate resources to the segments and to assess
their performance. The Group considers that it operates in a single operating
segment being the production and sale of gas.
6.16. BASIS OF GOING CONCERN ASSUMPTION
The Group's Production Sharing Contract (PSC) expired on 20 August 2024 and
had not been extended as at the date of these consolidated financial
statements. Management has formally applied for an extension of the PSC and
continues to engage with relevant authorities to secure its renewal.
The Gas Sales and Purchase Agreement (GSPA) with the Group's sole customer
expired on 30 September 2024. In its place, the Group entered into an Interim
Term Sheet for gas sales and purchases, which is extendable every six months.
The current Interim Term Sheet has been extended until 31 January 2026.
Management remains in active negotiations with the customer to establish a
long-term commercial arrangement. The repeated extensions of the Interim Term
Sheet, along with the customer's operational reliance on gas from the block to
support regional power generation, support the expectation of further
extensions or renewal of the GSPA.
In relation to the GSPA, an arbitration tribunal has been constituted to
address the ongoing dispute. Proceedings are underway, but no final award has
been issued to date. Independent legal advice indicates that an outflow of
economic resources arising from the arbitration is not currently considered
probable. Resolution of the matter is expected to be protracted (refer to Note
24).
Subsequent to the reporting date, the Group has continued to service the
borrowings and has arrangements in place to address maturing obligations.
These include expected internal cash generation and continued financial
support from majority shareholders. Gynia has confirmed that although the
outstanding shareholders loan is contractually repayable on demand, it will
not be recalled within the next 12 months. Management has prepared cash flow
forecasts and operating plans that reflect these arrangements and the Group's
available liquidity position.
Based on the factors and forecasts outlined above, management is confident
that the Group will be able to meet its obligations as they become due in the
ordinary course of business. However, despite these mitigating factors, the
expiration of the PSC and the lack of a finalized long-term GSPA introduce a
material uncertainty that could significantly impact the Group's ability to
continue operating as a going concern. Nevertheless, these financial
statements have been prepared on a going concern basis.
7. PROPERTY, PLANT AND EQUIPMENT
Property, plant and equipment comprise of the following:
Cost Land Extended well test equipment Production Bunk Houses Vehicles Other assets Capital work-in-progress Total
Development assets Assets
Balance as at 31 March 2023 167,248 9,131,202 878,686,885 393,696,456 7,869,575 4,963,923 1,695,265 3,024,746 1,299,235,299
Additions - 82,242 71,726,970 1,196,361 - - - 674,711 73,680,314
Transfers - - (14,609,388) 14,609,388 - - - - -
Disposals - - - - - - - - -
Balance as at 31 March 2024 167,248 9,213,444 935,804,466 409,502,205 7,869,575 4,963,923 1,695,265 3,699,497 1,372,915,613
Additions - - 20,140,425 - - - 13,378 40,637 20,194,440
Transfers - - (6,597,738) 8,292,163 571,579 - - (2,266,004) -
Disposals - - - - - (885,579) - - (885,579)
Balance as at 31 March 2025 167,248 9,213,444 949,347,153 417,794,368 8,441,154 4,078,344 1,708,643 1,474,130 1,392,224,474
Accumulated Depreciation
Balance as at 1 April 2023 - 3,129,668 - 59,656,825 6,412,709 4,916,324 1,685,294 - 75,800,820
Depreciation for the Year - 426,124 - 4,821,537 196,072 47,551 442 - 5,491,726
Balance as at 31 March 2024 - 3,555,792 - 64,478,363 6,608,781 4,963,875 1,685,736 - 81,292,547
Depreciation on assets transferred - - - - - (885,537) - - (885,537)
Depreciation for the year - 425,589 - 1,202,824 195,692 - 2,249 - 1,826,354
Impairment for the - 2,183,951 386,880,485 143,494,106 683,236 - 8,623 600,741 533,851,142
year
Balance as at 31 March 2025 - 6,165,332 386,880,485 209,175,292 7,487,709 4,078,338 1,696,608 600,741 616,084,506
Carrying values
At 31 March 2023 167,248 6,001,534 878,686,884 334,039,631 1,456,866 47,599 9,971 3,024,746 1,223,434,519
At 31 March 2024 167,248 5,657,652 935,804,466 345,023,843 1,260,794 48 9,529 3,699,497 1,291,623,066
At 31 March 2025 167,248 3,048,112 562,466,668 208,619,076 953,445 6 12,035 873,389 776,139,979
The balances above represent the Group's share in property, plant and
equipment as per note 3. Tangible assets comprise development /production
assets in respect of SGL, SSG and SSF fields.
Development assets of SGL, SSG and SSF fields includes the amount of
exploration and evaluation expenditure transferred to development cost on the
date of the first commercial discovery declared by the Group and also includes
expenditure incurred for the drilling of further wells in these fields to
enhance the production activity.
Production assets in respect of SGL field includes completed production
facilities. The Group commenced the production facility in October 2012, and
accordingly such production assets have been depreciated since this date.
The additions in development assets also include borrowing costs US$
13,465,472 (previous year: US$ 56,485,719). The weighted average
capitalization rate on funds borrowed generally is 6.80 per cent per annum
(previous year 6.76 per cent).
The depreciation has been included in the following headings-
31 March 2025 31 March 2024
Depreciation included in assets other than production assets 623,572 670,189
Depreciation included in statement of comprehensive income under the head cost 1,203,224 4,821,537
of sales for production assets
Total 1,826,796 5,491,726
The Group assessed the carrying value of its gas production assets in Block
RJ-ON/6 as at 31 March 2025 in accordance with IAS 36. Triggering events
included the expiry of the PSC and GSPA contract, declining production
volumes, adverse reservoir behaviour, and ongoing arbitration with GAIL
(India) Limited. The recoverable amount of the CGU was determined on a
value-in-use basis using discounted cash flow forecasts. Refer to note 25 for
additional disclosures on impairment.
8. DEFERRED TAX ASSETS/ LIABILITIES (NET)
Deferred taxes arising from temporary differences are summarized as follows:
31 March 2025 31 March 2024
Deferred tax assets 404,038,277 404,038,277
Impairment Loss 160,142,858 -
Total 564,181,135 404,038,277
Deferred tax liability
Development assets/ property, plant and equipment 564,181,135 564,181,135
Total 564,181,135 564,181,135
Net deferred tax liabilities - 160,142,858
a) The deferred tax movements during the current year have been
recognized in the consolidated statement of comprehensive income.
b) The deferred tax on the Impairment of assets has been recognized only
to the extent of the deferred tax liability.
c) The Group has recognized deferred tax assets on deductible temporary
differences and unused tax losses/credits to the extent that they can be
offset against taxable temporary differences represented by existing deferred
tax liabilities within the same jurisdiction.
9. INCOME TAXES
Income tax is based on the tax rates applicable on profit or loss in various
jurisdictions in which the Group operates. The effective tax at the domestic
rates applicable to profits in the country concerned as shown in the
reconciliation below have been computed by multiplying the accounting profit
by the effective tax rate in each jurisdiction in which the Group operates.
The individual entity amounts have then been aggregated for the consolidated
financial statements. The effective tax rate applied in each individual entity
has not been disclosed in the tax reconciliation below as the amounts
aggregated for individual Group entities would not be a meaningful number.
Income tax credit is arising on account of the following:
31 March 2025 31 March 2024
Current tax charge (10,253,484) (15,749,906)
Total (10,253,484) (15,749,906)
The relationship between the expected tax expense based on the domestic tax
rates for each of the legal entities within the Group and the reported tax
expense in consolidated statement of comprehensive income is reconciled as
follows:
31 March 2025 31 March 2024
Accounting profit for the year before tax 26,457,702 36,120,698
Effective tax at the domestic rates applicable to profits in the country 10,084,447 15,696,477
concerned
Tax impact of bought forward losses lapsed during the year - -
Non-taxable income 169,037 53,429
Other - -
Tax expense 10,253,484 15,749,907
The reconciliation shown above has been based on the rate 38.22 per cent
(previous year: 43.68 per cent) as applicable under Indian tax laws.
The Group's profits are taxable as per the tax laws applicable in Guernsey
where zero per cent tax rate has been prescribed for corporate. Accordingly,
there is no tax liability for the Group in Guernsey. IServices and Newbury
being participants in the PSC are covered under the Indian Income tax laws as
well as tax laws for their respective countries. However, considering the
existence of double tax avoidance arrangement between Cyprus and India, and
Mauritius and India, profits in Newbury and iServices are not likely to
attract any additional tax in their local jurisdiction. Under Indian tax laws,
Newbury and iServices are allowed to claim the entire expenditure incurred in
respect of the respective fields in the Oil Block until the start of
commercial production (whether included in the exploration and evaluation
assets or development assets) as deductible expense in the first year of
commercial production or over a period of 10 years. The Group has opted to
claim the expenditure in the first year of commercial production. As the Group
has commenced commercial production for SGL, SSG and SSF field and has
generated profits in Newbury and iServices, the management believes there is
reasonable certainty of utilization of such losses in the future years and
thus a deferred tax asset has been created in respect of these.
10. INVENTORIES
Inventories comprise the following:
31 March 2025 31 March 2024
Drilling and production stores and spares 6,839,390 8,862,398
Fuel 31,454 36,024
Goods in transit 27,779 46,267
Total 6,898,623 8,944,689
The above inventories are held for use in the exploration, development and
production activities. These are valued at cost determined based on policy
explained in paragraph 6.10. Inventories of US$ 80,456 (previous year: US$
275,190) were recorded as an expense under the heading 'cost of sales' in the
consolidated statement of comprehensive income during the year ended 31 March
2025. Inventories of US$ 3,091,919 (previous year: US$ 8,623,730) were
capitalized as part of development assets.
11. TRADE AND OTHER RECEIVABLES
31 March 2025 31 March 2024
Trade receivable 599,059 579,028
Other Current Asset 39,161 42,636
Total 638,220 621,664
The carrying amount of trade receivables approximates their fair values. Refer
"Credit risk" in note 29 for further information.
12. CASH AND CASH EQUIVALENTS
31 March 2025 31 March 2024
Cash at banks in current accounts 240,220 2,069,244
Total 240,220 2,069,244
The Group only deposits cash surpluses with major banks of high-quality credit
standing.
13. EQUITY
Authorized share capital
The total authorized share capital of the Group is GBP 5,000,000 divided into
500,000,000 shares of GBP 0.01 each.
Issued share capital
The total issued share capital of the Group is US$ 3,619,443 (previous year:
3,619,443) divided into 182,973,924 shares (previous year: 182,973,924).
--For all matters submitted to vote in the shareholders meeting of the Group,
every holder of ordinary shares, as reflected in the records of the Group on
the date of the shareholders' meeting has one vote in respect of each share
held.
All shareholders are equally eligible to receive dividends and the repayment
of capital in the event of liquidation of the individual entities of the
Group.
Additional paid in capital
Additional paid-in capital represents excess over the par value of share
capital paid in by shareholders in return for the shares issued to them,
recorded net of expenses incurred on issue of shares.
Currency translation reserve
Currency translation reserve represents the balance of translation of the
entity's financial statements into US$ until 30 November 2010 when its
functional currency was assessed as GBP. Subsequent to 1 December 2010, the
functional currency of Indus Gas was reassessed as US$.
Merger reserve
The balance on the merger reserve represents the fair value of the
consideration given in excess of the nominal value of the ordinary shares
issued in an acquisition made by the issue of shares of subsidiaries from
other entities under common control.
Retained earnings/(losses)
Retained earnings/(losses) include current and prior period retained profits.
14. LONG TERM DEBT
From Banks
Maturity 31 March 2025 31 March 2024
Non-current portion of long-term debt November 2024 (PY: November 2024) - -
Current portion of long-term debt - 16,237,543
Total - 16,237,543
Current interest rates are variable and weighted average interest for the year
was 8.09 per cent per annum (previous year: 5.80 per cent per annum). The fair
value of the above variable rate borrowings is considered to approximate their
carrying amounts. The maturity profile (undiscounted) is explained in note 28.
Interest capitalised on loans above have been disclosed in notes 7.
The term loans are secured by following: -
· First charge on all project assets of the Group both present and
future, to the extent of SGL Field Development and to the extent of CapEx
incurred out of this facility in the rest of RJ-ON/6 field.
· First charge on the current assets (inclusive of condensate receivable)
of the Group to the extent of SGL field.
· First Charge on the entire current assets of the SGL Field and to the
extent of CapEx incurred out of this facility in the rest of RJON/6 field.
From Bonds
Maturity 31 March 2025 31 March 2024
Non-current portion of long-term debt 2027 159,581,721 159,689,118
Current portion of long-term debt 4,505,626 4,337,778
Total 164,087,347 164,026,896
The Group had issued US Dollar 160.00 million bonds which carries interest at
the rate of 8 per cent per annum, for the purpose of re-financing the bonds
which were repayable in December 2022. These bonds are unsecured bonds and are
fully repayable at the end of 5 years i.e., November 2027, further interest on
these notes is paid semi-annually.
15. PROVISION FOR DECOMMISSIONING
Amount
Balance at 1 April 2023 1,894,796
(Decrease) in provision (13,190)
Balance as at 31 March 2024 1,881,606
Increase in provision 18,000
Balance as at 31 March 2025 1,899,606
As per the PSC, the Group is required to carry out certain decommissioning
activities on gas wells. The provision for decommissioning relates to the
estimation of future disbursements related to the abandonment and
decommissioning of gas wells. The provision has been estimated by the Group's
engineers, based on individual well filling and coverage. This provision will
be utilized when the related wells are fully depleted. The majority of the
cost is expected to be incurred within a period of the next 4 years.
16. PAYABLE/ RECEIVABLE TO RELATED PARTIES
Related parties payable comprise the following:
Maturity 31March 2025 31March 2024
Current
Payable to directors 43,762 12,656
43,762 12,656
Current
Borrowings from Gynia Holdings Ltd.* On demand 709,560,347 678,410,347
709,560,347 678,410,347
Total 709,604,109 678,423,003
* During the previous financial year, borrowings from Gynia Holdings Ltd. bore
interest at the rate of 6.5% per annum, compounded annually. However, in the
current financial year, Gynia Holdings Ltd., being the holding Group, has
waived the interest on such borrowings. As outstanding amount remains
repayable on demand, it has been reclassified to current liabilities in the
current year. Gynia has confirmed that although the contractually repayable on
demand, the outstanding amount will not be recalled within the next 12 months
Interest capitalised on loans above have been disclosed in note 7.
Related parties' receivable comprises the following:
31 March 2025 31 March 2024
Current
Prepayments due from Focus 99,813,280 98,023,733
Other assets due from Focus 9,426,690 9,281,833
Total 109,239,970 107,305,566
Prepayments and other assets due from Focus
Prepayments to Focus represents excess amounts paid to them in respect of the
Group's share of contract costs, for its participating interest in Block
RJ-ON/6 pursuant to the terms of Agreement for Assignment dated 13 January
2006 and its subsequent amendments from time to time.
Other assets comprises of the amount of royalty recoverable from Focus Energy
Limited.
17. TRADE AND OTHER PAYABLES
31March 2025 31March 2024
Trade payables 1,222,328 1,129,705
VAT payables 54,454 52,974
Other liabilities 325,742 343,301
1,602,524 1,525,980
The carrying amount of trade and other payable approximates their fair values
and are non-interest bearing.
18. REVENUE
The Group's revenue disaggregated by primary geographical markets is as
follows:
31March 2025 31March 2024
Revenue from operations 29,651,641 42,930,441
Total Income 29,651,641 42,930,441
The Group's revenue disaggregated by the portion of revenue recognition is as
follows:
31March 2025 31March 2024
Goods transferred at a point in time 29,630,355 42,867,982
Total 29,630,355 42,867,982
Sale of Goods (Gas)
The revenue majorly pertains to the sale of natural gas and condensate
production (by-product). The Group sells its natural gas to GAIL at a price
fixed under the agreement. The condensate is sold in the open market through
bidding. Further, the Group has entered into a gas sale agreement wherein the
customer is to be liable to pay 41 % (Previous year: 41%) of the annual
contracted quantity if the customer does not purchase gas during the financial
year.
Contractual assets and Contractual Liabilities
31 March 2025 31 March 2024
Current Non-current Current Non-current
Opening balance of Contract liabilities Deferred revenue 25,470,135 - - 30,311,748
Less: Amount adjusted against trade receivables - - - (4,841,613)
Add: Transfer from non-current to current liabilities - 25,470,135 (25,470,135)
Less: Amount written off during the year 25,470,135 - -
Closing balance of Contract liabilities - Deferred revenue - - 25,470,135 -
The Group has recognized income on account of expiry of all rights of GAIL to
receive make-up gas under the Gas Sale and Purchase Agreement ("GSPA"), which
automatically lapsed on 1st February 2025. Although GAIL has initiated
arbitration proceedings in relation to this matter, based on detailed legal
advice obtained by the Company, the management is of the view that no present
obligation exists and, accordingly, no liability is expected to arise against
the Group in the future
19. EMPLOYEE COST
Per the PSC, Focus is the Operator of the Block. For SGL field, ONGC has a
participative interest of 30% in the development cost. Hence, the share of
iServices and Newbury are proportionately reduced (i.e., 45.5% and 17.5%
respectively). For the Non-SGL field, the share of iServices, Newbury and
Focus are in the ratio of 65%, 25% and 10% respectively. The Employee cost
attributable to Indus Gas Limited has been allocated in the agreed ratio
(refer note 3) by Focus and recorded as cost of sales and administrative
expenses in the consolidated statement of comprehensive income amounting to
US$ 540,568(previous year US$ 197,976) and US$ 356,668 (previous year US$
317,758) respectively. Cost pertaining to the employees of the Group have been
included under administrative expense is US$ 165,066 (previous year US$
172,274).
20. FOREIGN CURRENCY EXCHANGE (LOSS)/ GAIN, NET
The Group has recognized the following in the consolidated statement of
comprehensive income on account of foreign currency fluctuations:
31 March 2025 31 March 2024
(Loss) on restatement of foreign currency monetary receivables and payables (19,889) (22,284)
22,852 (412,553)
Gain arising on settlement of foreign currency transactions and restatement of
foreign currency balances arising out of Oil block operations.
Total 2,963 (434,837)
21. EARNINGS PER SHARE
The calculation of the basic earnings per share is based on the earnings
attributable to ordinary shareholders divided by the weighted average number
of shares in issue during the year. Calculation of basic and diluted earnings
per share is as follows:
31 March 2025 31 March 2024
Profits attributable to shareholders of Indus Gas Limited, for basic and (357,576,415) 20,185,252
dilutive
182,973,924 182,973,924
Weighted average number of shares (used for basic earnings per share)
182,973,924 182,973,924
Diluted weighted average number of shares (used for diluted earnings per
share)
Basic earnings per share (1.95) 0.11
Diluted earnings per share (1.95) 0.11
22. RELATED PARTY TRANSACTIONS
The related parties for each of the entities in the Group have been summarised
in the table below:
Nature of the relationship Related Party's Name
I. Holding Company Gynia Holdings Ltd.
Multi Asset Holdings Ltd. (Holding Company of Gynia Holdings Ltd.)
II. Ultimate Holding Company
III. Enterprises over which Key Management Personnel (KMP) exercise control Focus Energy Limited
(with whom there are transactions)
Disclosure of transactions between the Group and related parties and the
outstanding balances as at 31 March 2025 and 31 March 2024 is as under:
Transactions with Holding Company
Particulars 31 March 2025 31 March 2024
Transactions during the year with the holding Company
Amount Received 31,625,000 9,877,100
Amount Paid (475,000) (6,500,000)
Interest - 41,109,047
Balances at the end of the year
Total payable* 709,560,347 678,410,347
*Including interest
Transactions with KMP and entity over which KMP exercise control
Particulars 31 March 2025 31 March 2024
Transactions during the year
Remuneration to KMP
Short term employee benefits 165,066 172,274
Total 165,066 172,274
Entity over which KMP exercise control
Cost incurred by Focus on behalf of the Group in respect of the Block 4,656,806 17,320,604
Remittances to Focus 6,591,211 17,278,000
Balances at the end of the year 109,239,970 107,305,566
Total receivables
Total payable (43,762) (12,656)
Directors' remuneration
Directors' remuneration is included under administrative expenses, evaluation
and exploration assets or development assets in the consolidated financial
statements allocated on a systematic and rational manner. Remuneration by
director is separately disclosed in the directors' report on page 7.
23. SEGMENT REPORTING
The Chief Operating Decision Maker being the Chief Executive Officer of the
Group, reviews the business as one operating segment being the extraction and
production of gas. The operating segments have been aggregated due to similar
economic characters and allied nature of product and services. Hence, no
separate segment information has been furnished herewith.
All of the non-current assets other than financial instruments and deferred
tax assets (there are no employment benefit assets and rights arising under
insurance contracts) are located in India and amounted to US$ 776,139,979
(previous year: US$ 1,291,623,477).
Revenue from customers have been identified on the basis of the customer's
geographical location and are disclosed in note 18. The total revenue from the
Group is from the sale of natural gas, its by-products (i.e., condensate) to
Oil and gas exploration companies. The revenue from the top customer comprises
96.06% (Previous year: 95.10%) of the Group's total revenue.
24. COMMITMENTS AND CONTINGENCIES
The Group has no commitments as at 31 March 2025 (previous year Nil).
The Company, together with its group entities, is a respondent in an
arbitration initiated by GAIL (India) Limited under the Gas Sale and Purchase
Agreement dated 7 August 2009 relating to supply of natural gas from Block
RJ-ON/6 in Rajasthan. GAIL has raised claims for refund of Take-or-Pay amounts
and other contractual entitlements. The Respondents have filed a defence and
counter-claims.
The matter is currently under arbitration and is subject to interpretation of
contractual provisions and resolution of factual disputes. Based on legal
advice, management is of the view that the claims are not sustainable, and
considers that it is not probable that an outflow of resources will be
required. Accordingly, no provision has been recognised. However, given the
status of proceedings, the matter represents a contingent liability whose
outcome cannot be determined at this stage.
No adjustment has been made in the accompanying financial statements in
respect of this matter.
25. ACCOUNTING ESTIMATES AND JUDGEMENTS
In preparing consolidated financial statements, the Group's management is
required to make judgments and estimates that affect the reported amounts of
assets and liabilities and the disclosure of contingent assets and liabilities
at the date of the financial statements and the reported amounts of revenues
and expenses during the reporting period. The judgments and estimates are
based on management's best knowledge of current events and actions and actual
results from those estimates may ultimately differ.
Significant judgments applied in the preparation of the consolidated financial
statements are as under:
Determination of functional currency of individual entities
Following the guidance in IAS 21 "The effects of changes in foreign exchange
rates", the functional currency of each individual entity is determined to be
the currency of the primary economic environment in which the entity operates.
In the management's view each of the individual entity's functional currency
reflects the transactions, events and conditions under which the entity
conducts its business. The management believes that US$ has been taken as the
functional currency for each of the entities within the Group. US$ is the
currency in which each of these entities primarily generate and expend cash
and also generate funds for financing activities.
Going concern
Management has exercised significant judgement in concluding that the Group is
a going concern, taking into account the expiry of the PSC and GSPA, the
Group's liquidity and majority shareholder support (note 6.16), and the
ongoing arbitration proceedings with GAIL (note 24), . While the financial
statements are prepared on a going concern basis, these factors give rise to
material uncertainties which may cast significant doubt on the Group's ability
to continue as a going concern.
Full cost accounting for exploration and evaluation expenditure
The Group has followed 'full cost' approach for accounting for exploration and
evaluation expenditure against the 'successful efforts' method. As further
explained in note 6.6, exploration and evaluation assets recorded using 'full
cost' approach are tested for impairment prior to reclassification into
development assets on successful discovery of gas reserves.
Impairment of tangible assets
The Group follows the guidance of IAS 36 and IFRS 6 to determine when a
tangible asset is impaired. This determination requires significant judgment
to evaluate indicators triggering impairment. The Group monitors internal and
external indicators of impairment relating to its tangible assets. For the
purpose of impairment assessment, judgements are involved in estimating the
expected gas extraction from production assets, based on which, indicators are
identified necessary for determining that an impairment assessment is
necessary. Based on management assessment, the management has carried out
impairment testing for impairment of property, plant and equipment as at 31
March 2025.
Revenue Recognition on expiry of restoration period
The Group has recognised revenue of US$ 23.58 million during the year ended 31
March 2025 following the release of deferred income previously recorded in
respect of Annual Take-or-Pay (AToP) payments received under the Gas Sale and
Purchase Agreement ("GSPA") with GAIL (India) Limited.
Management has exercised significant judgement in concluding that this
deferred income should be recognised as revenue on the basis that:
· The contractual Restoration Period under the GSPA expired on 31
January 2025, at which point the Buyer's rights to offtake Make-Up Gas ceased.
· No further performance obligations remained under the contract
after this date.
This judgement reflects management's interpretation of the GSPA and
application of IFRS 15, under which revenue is recognised when (or as)
performance obligations are satisfied.
Estimates used in the preparation of the consolidated financial statements:
Useful life and residual value of tangible assets
The Group reviews the estimated useful lives of property, plant and equipment
at the end of each annual reporting period. Specifically, production assets
are depreciated on a basis of unit of production (UOP) method which involves
significant estimates in respect of the total future production and estimate
of reserves. The calculation of UOP rate of depreciation could be impacted to
the extent that the actual production in future is different from the
forecasted production. During the financial year, the directors determined
that no change to the useful lives of any of the property, plant and equipment
is required. The carrying amounts of property, plant and equipment have been
summarized in note 7.
Recognition of provision for decommissioning cost
As per the PSC, the Group is required to carry out certain decommissioning
activities on gas wells. The ultimate decommissioning costs are uncertain and
cost estimates can vary in response to many factors including changes to
relevant legal requirements, the emergence of new restoration techniques or
experience at other production sites. The expected timing and amount of
expenditure can also change, for example, in response to changes in reserves
or changes in laws and regulations or their interpretation. As a result, there
could be adjustments to the provisions established which would affect future
financial results. The liabilities estimated in respect of decommissioning
provisions have been summarized in note 15.
Impairment testing
As explained above, management carried out impairment testing of property,
plant and equipment as on 31 March 2025. An impairment loss is recognized for
the amount by which the asset's or cash generating unit's carrying amount
exceeds its recoverable amount.
To determine the recoverable amount, management estimates expected future cash
flows from the Block and determines a suitable interest rate in order to
calculate the present value of those cash flows. In the process of measuring
expected future cash flows management makes assumptions about future gross
profits. These assumptions relate to future events and circumstances. In most
cases, determining the applicable discount rate involves estimating the
appropriate adjustment to market risk and the appropriate adjustment to
asset-specific risk factors.
The recoverable amount was determined based on value-in-use calculations;
basis gas reserves confirmed by an independent competent person. The discount
rate calculation is based on the Company's weighted average cost of capital
adjusted to reflect post-tax discount rate and amounts to 12.04% p.a.
In line with regulatory expectations for transparent sensitivity disclosures,
management has performed scenario-based sensitivity analysis by isolating the
impact of key revenue drivers production and price while adjusting the
discount rate. The results are as follows:
US$ (In million)
Particulars Carrying value of Property, Plant & Equipment
Reduction in price by 1% and increase in discount rate by 1% 732.75
Reduction in production by 1% and increase in discount rate by 1% 727.40
Increase in price by 1% and decrease in discount rate by 1% 828.91
Increase in production by 1% and decrease in discount rate by 1% 833.20
This approach provides a view of how changes in individual revenue components
price or production volume impact on the recoverable amount, while keeping
other variables constant.
Deferred tax assets
The assessment of the probability of future taxable income in which deferred
tax assets can be utilized is based on the management's assessment, which is
adjusted for specific limits to the use of any unused tax loss or credit. The
tax rules in the jurisdictions in which the Group operates are also carefully
taken into consideration. If a positive forecast of taxable income indicates
the probable use of a deferred tax asset, then deferred tax asset is usually
recognized in full. The recoverability of deferred tax assets is monitored as
an ongoing basis based on the expected taxable income from the sale of gas.
26. CAPITAL MANAGEMENT POLICIES
The Group's objectives when managing capital are to safeguard the Group's
ability to continue as a going concern in order to provide returns for
shareholders and benefits for other stakeholders and to maintain an optimal
capital structure to reduce the cost of capital.
The Group manages the capital structure and adjusts it in the light of changes
in economic conditions and the risk characteristics of the underlying assets.
The Group monitors capital on the basis of the gearing ratio. This ratio is
calculated as net debt divided by total capital. Debt is calculated as total
liabilities (including 'current and non-current liabilities' as shown in the
consolidated Statement of Financial Position). Total capital employed is
calculated as 'equity' as shown in the consolidated statement of financial
position plus total debt.
31 March 2025 31 March 2024
Total debt (A) 887,447,073 1,047,708,021
Total equity (B) 6,052,159 363,628,576
Total capital employed (A+B) 893,499,232 1,411,336,597
Gearing ratio 99.32 % 74.26 %
The gearing ratio has increased in the current year to 99.32% from 74.26% in
the prior year, primarily due to a proportionately higher draw-down of loans
from a related party. Further, during the current year decrease in gearing
ratio can also be attributed to a reduction in equity resulting from the
recognition of impairment losses increase in equity
The Group is not subject to any externally imposed capital requirements. There
were no changes in the Group's approach to capital management during the year.
27. FINANCIAL INSTRUMENTS AND RISK MANAGEMENT
A summary of the Group's financial assets and liabilities by category are
mentioned in the table below. The carrying amounts of the Group's financial
assets and liabilities recognized at the end of the reporting period are as
follows:
31 March 2025 31 March 2024
Non-current assets
Loans
- Security deposits 8,958 8,722
Current assets
- Trade receivables 638,230 621,664
- Cash and cash equivalents 240,220 2,069,244
- Prepayment and other assets due from a related party 109,239,970 107,305,566
Total financial assets under loans and receivables 110,127,378 110,005,196
Non-current liabilities
Financial liabilities measured at amortized cost:
- Long term debt 159,581,721 159,689,118
- Payable to related parties - 678,410,347
Current liabilities
Financial liabilities measured at amortized cost:
- Current portion of long-term debt 4,505,626 20,575,321
- Current portion of payable to related parties 709,604,109 12,656
- Trade and other payables (other than VAT payable) 1,548,070 1,473,006
Total financial liabilities measured at amortized cost 875,239,526 860,160,448
The fair value of the financial assets and liabilities described above closely
approximates their carrying value on the statement of financial position date.
Risk management objectives and policies
The Group finances its operations through a mixture of loans from banks and
related parties and equity. Finance requirements such as equity, debt and
project finance are reviewed by the Board when funds are required for
acquisition, exploration and development of projects.
The Group treasury functions are responsible for managing funding requirements
and investments which includes banking and cash flow management. Interest and
foreign exchange exposure are key functions of treasury management to ensure
adequate liquidity at all times to meet cash requirements.
The Group's principal financial instruments are cash held with banks and
financial liabilities to banks and related parties and these instruments are
for the purpose of meeting its requirements for operations. The Group's main
risks arising from financial instruments are foreign currency risk, liquidity
risk, commodity price risk and credit risks. Set out below are policies that
are used to manage such risks.
Foreign currency risk
The functional currency of each entity within the Group is US$ and the
majority of its business is conducted in US$. All revenues from gas sales are
received in US$ and substantial costs are incurred in US$. No forward exchange
contracts were entered into during the year.
Entities within the Group conduct the majority of their transactions in their
functional currency other than amounts of cash held in GBP, SGD and INR. All
other monetary assets and liabilities are denominated in functional currencies
of the respective entities. The currency exposure on account of assets and
liabilities which are denominated in a currency other than the functional
currency of the entities of the Group as at 31 March 2025 and 31 March 2024 is
as follows:
Particulars Functional currency Foreign currency 31 March 2025 31 March 2024
(Amount in US$) (Amount in US$)
Short term exposure- US$ Great Britain Pound 29,739 36,730
Cash and cash equivalents
US$ Singapore Dollar 10,714 10,647
US$ Indian Rupee 111,767 147,906
Total exposure 152,220 195,283
As at March 31, 2025 every 1% (increase)/decrease of the respective foreign
currencies compared to the functional currency of the Group entities would
impact profit before tax by approximately US$ (1,522) and US$ 1,522
respectively.
Liquidity risk
Ultimate responsibility for liquidity risk management rests with the Board of
Directors, which has established an appropriate liquidity risk management
framework for the management of the Group's short, medium and long-term
funding and liquidity management requirements. The Group manages liquidity
risk by maintaining adequate reserves, banking facilities and reserve
borrowing facilities, by continuously monitoring forecast and actual cash
flows, and by matching the maturity profiles of financial assets and
liabilities.
The table below summaries the maturity profile of the Group's financial
liabilities based on contractual undiscounted payments for the liquidity
analysis.
On demand 3 months to 1 year 1-2 years 2-5 years 5+ years Total
0-3 months
31 March 2025
Non-interest bearing - - - - 711,162,873
709,560,347 1,602,526
Variable interest rate liabilities - - - - -
-
-
Fixed interest rate liabilities - - - 159,581,721 - 164,087,347
4,505,626
709,560,347 6,108,152 - - 159,581,721 - 875,250,220
On demand 3 months to 1 year 1-2 years 2-5 years 5+ years Total
0-3 months
31 March 2024
Non-interest bearing - - - - - 1,485,662
1,485,662
Variable interest rate liabilities - 10,649,222 - - - 16,237,545
5,588,323
Fixed interest rate liabilities - - - 838,099,463 - 842,437,241
4,337,778
11,411,763 10,649,222 - 838,099,463 - 860,160,448
Interest rate risk
The Group's policy is to minimize interest rate risk exposures on the
borrowing from the banks and the sum payable to Focus Energy Limited.
Borrowing from the Gynia Holdings Ltd. is at fixed interest rate and
therefore, does not expose the Group to risk from changes in interest rate.
The interest rate on bond is fixed at 8% per annum. The Group is exposed to
changes in market interest rates through bank borrowings at variable interest
rates.
The Group's interest rate exposures are concentrated in US$.
The analysis below illustrates the sensitivity of profit and equity to a
reasonably possible change in interest rates. Based on volatility in interest
rates in the previous 12 months, the management estimates a range of 50 basis
points to be approximate basis for the reasonably possible change in interest
rates. All other variables are held constant.
Interest rate
+ 0.50 per cent - 0.50 per cent
31 March 2025 - -
31 March 2024 81,188 81,188
Since the loans are taken for the general corporate purpose and according to
the Group's policy the certain borrowing costs related to development
activities are capitalized on account of general borrowings at an average rate
of borrowings to the cost of the development asset.
Commodity price risks
The Group's share of gas production from the Block is sold to GAIL, its sole
customer. The gas price is determined monthly by the Petroleum Planning &
Analysis Cell (PPAC) in accordance with the domestic gas pricing guidelines,
which are based on 10% of the monthly average of the Indian crude oil basket.
The Group has not entered into any commodity price hedging contracts and
remains exposed to fluctuations in the regulated domestic gas price.
Credit risk
Credit risk is the risk that a counterparty will not meet its obligations
under a financial instrument or customer contract, leading to a financial
loss. The Group is exposed to credit risk from its operating activities
(primarily trade receivables) and from its financing activities, including
deposits with banks and financial institutions. The Group considers the impact
of credit risk to be insignificant on the basis of the reputable credit
standing of the respective counterparties. The management has evaluated the
impact of expected credit loss on the receivable balance. While evaluating the
same, macroeconomic factors affecting the customer's ability to settle the
amount outstanding have been considered. The Group has identified gross
domestic product (GDP) and unemployment rates of the countries in which the
customers are domiciled to be the most relevant factors. The impact was
insignificant and accordingly no adjustment has been recorded in the financial
statements.
Other receivables such as security deposits and cash and cash equivalents do
not comprise of a significant balance and thus do not expose the Group to a
significant credit risk.
The tables below detail the credit quality of the Group's financial assets and
other items, as well as the Group's maximum exposure to credit risk by credit
risk rating grades.
Internal credit rating 12M or Lifetime ECL Gross carrying amount Loss allowance Net carrying amount
31 March 2025
Security deposits Performing 12 Month ECL 8,958 - 8,958
Performing Lifetime ECL (simplified approach) 638,220 - 638,220
Trade receivables
Cash and cash equivalents Performing 12 Month ECL 240,220 - 240,220
Other assets due from a related party Performing 12 Month ECL 9,426,690 - 9,426,690
10,314,088 - 10,314,088
Internal credit rating 12M or Lifetime ECL Gross carrying amount Loss allowance Net carrying amount
31 March 2024
Security deposits Performing 12 Month ECL 8,722 - 8,722
Trade receivables Performing Lifetime ECL 621,664 - 621,664
(Simplified approach)
Cash and cash equivalents Performing 12 Month ECL 2,069,244 - 2,069,244
Prepayment and other assets due from a related party Performing 12 Month ECL 9,281,833 - 9,281,833
11,981,463 - 11,981,463
Performing
12 Month ECL
9,281,833
-
9,281,833
11,981,463
-
11,981,463
An asset is performing when the counterparty has a low risk of default.
28. RECONCILIATION OF LIABILITIES FROM FINANCING ACTIVITIES
Borrowings
As at April 01, 2023 838,191,442
Cash Movement:
Net proceeds 9,877,100
Net utilisation (34,454,400)
Other non- cash movements
Impact of effective interest rate adjustment (694,512)
Impact of exchange fluctuations -
Interest accruals 45,767,811
Net debts as at March 31, 2024 858,687,441
Borrowings
As at April 01, 2024 858,687,441
Cash Movement:
Net proceeds 31,150,000
Net utilisation (20,651,611)
Other non- cash movements
Impact of effective interest rate adjustment 203,404
Impact of exchange fluctuations -
Interest accruals 4,302,222
Net debts as at March 31, 2025 873,691,456
29. POST REPORTING DATE EVENT
No adjusting or significant non-adjusting event have occurred between 31 March
2025 and the date of authorization.
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