Bengal Energy Announces Fiscal 2022 Third Quarter Results
Calgary, Alberta--(Newsfile Corp. - February 10, 2022) - Bengal Energy Ltd. (TSX: BNG) ("Bengal" or the "Company") today announces its financial and operating results for the third quarter of fiscal 2022 ended December 31, 2021.
THIRD QUARTER FISCAL 2022 HIGHLIGHTS:
The following is an overview of the financial and operational results during the three-and nine-months ending December 31, 2022. All amounts are in Canadian funds, unless otherwise noted:
Sales Revenue - Crude oil sales revenue was $1.8 million in the third quarter fiscal 2022, which is 45% higher than the $1.3 million recorded in Q3 fiscal 2021 as decreased production was offset by increased commodity prices. Benchmark Brent price during the current quarter averaged US $85.11 per barrel of crude oil ("bbl") compared to US $47.38 per bbl for the same quarter in fiscal 2021.
Funds and cashflow from Operations1 - Bengal generated $0.6 million of cash from operating activities during Q3 fiscal 2022 compared to $0.1 million Q3 fiscal 2021. Funds from operations were $0.4 million during fiscal Q3 2022 compared to $0.1 million in Q3 fiscal 2021.
Net Income - Bengal reported net loss of $0.5 million for the current quarter compared to net income of $0.7 million in the third quarter fiscal 2021. During the current quarter there were no gains on hedging activity and an impairment charge of $0.6 million associated with uneconomic drilling results.
Production Volumes - The Company's share of light crude oil production in the current quarter was 16,865 bbls, which represents a 13% decrease from the 19,444 bbls produced in the third quarter fiscal 2021. The current quarter production averaged 183 bbls/d compared to 211 bbls/d produced in the third quarter fiscal 2021. The decline in production is a result of natural reservoir decline.
Capital Expenditures - Bengal incurred $1.4 million in capital expenditures during Q3 fiscal 2022 as compared to $0.5 million in Q3 fiscal 2021. The majority of the current quarter expenditures relate to site preparation and preliminary activities to support the Company's future development plans at its recently acquired 100% working interest tenures (Petroleum Leases ("PL"), Authority to Prospect ("ATP", Petroleum Pipeline Lease ("PPL")): PL 1110 Wareena, ATP 732, and PPL 138 pipeline. During the quarter, the Company recorded $0.6 million of impairment associated with uneconomic drilling results at the Chef-1 location.
934 Exploration Well - During the quarter Santos drilled the Legbar exploration well at no cost to Bengal to earn a 60% interest in the southern portion of the block. The well was plugged and abandoned.
|($000s except per share, %, volumes and operating netback amounts||Three months ended September 30,||Six months ended September 30,|
|Cashflow from operations||$||607||$||62||$||398||$||231|
|Funds from (used in) operations(2)||$||381||$||130||$||917||$||(147||)|
|Per share ($) (basic and diluted)||$||0.00||$||0.00||$||0.00||$||(0.00||)|
|Per share ($) (basic and diluted)||$||(0.00||)||$||0.01||$||(0.00||)||$||0.01|
|Oil volumes (bbls/d)||183||211||186||227|
|Operating netback(1) ($/bbl)||$||64.58||$||42.37||$||52.47||$||33.45|
(1) Operating netback is a non-IFRS measure and includes realized gain (loss) on financial instruments. Operating netback per bbl is calculated by dividing revenue (including realized gain (loss) on financial instruments) less royalties and operating costs by the total production of the Company measured in bbls.
(2) Funds from (used in) operations is a non-IFRS measure which is calculated by adding back all non-cash expense deductions to the net loss for the quarter and fiscal year. Funds from (used in) operations per share is a non-IFRS measure calculated as calculated by dividing funds from (used in) operations by weighted average basic and diluted shares outstanding for the periods disclosed. A reconciliation of the measures can be found in the table on page 14 of the December 31, 2021 MD&A.
Bengal has filed its consolidated financial statements and management's discussion and analysis for the quarter ended December 31, 2021, with the Canadian securities regulators. The documents are available on SEDAR at www.sedar.com or by visiting Bengal's website at www.bengalenergy.ca.
AUSTRALIA - Cooper Basin, Queensland
PL303 and PL 1028 Cuisinier (controlling permit ATP 752) (30.357% WI)
A pilot reservoir pressure maintenance scheme was initiated during the prior fiscal year and after resolving mechanical issues, water injection activities resumed during calendar Q4 2021. The location of this pilot is in the southeast quadrant of the Cuisinier pool, with injection of water taking place at the Cuisinier 24 well. The broad nature of the Cuisinier structure combined with variable flank aquifer pressure support has resulted in pressure depletion within the central portion of the Cuisinier pool. The injection of produced formation water is anticipated to both increase production in up to four offsetting wells and reduce water handling charges. On establishing success of the pilot, the Joint Venture ("JV") will begin a multi phase water injection scheme, targeted fracture stimulation and more commercially efficient development drilling. Since inception, 21,800 barrels of water have been injected into the C24 well at a rate of approximately 300 barrels of water per day. Nearby wells are being monitored for total fluid produced and water cut to help to determine which wells are being affected by the pilot program. Mechanical issues through commissioning have caused periods of downtime and full injection capability is expected to resume by mid-February.
During the quarter, Bengal participated in the Chef exploration drilling project. Following a review of the well logs, the ATP 752 JV parties have decided to plug and abandon the well. This exploration well is located outside of the producing Cuisinier field Petroleum Lease 303 ("PL 303"), in a location 4 km to the northeast with primary targets in the Jurassic Birkhead Formation and Hutton Sandstone, and secondary targets within the Triassic Nappamerri Group. The well encountered multiple oil shows in the primary and secondary targets; however, no commercial pay was identified at this location. While not a commercial success, the identified oil shows may support continued exploration targeting both the Jurassic Birkhead and newly discovered oil bearing Triassic Nappamerri formations.
ATP 934 Barrolka (100% WI)
ATP 934 is the Company's 100% owned natural gas exploration block. Bengal received special amendment approved for ATP 934 in March 2021 which relinquished 50% of the existing ATP area and extended the term of the ATP by entering into an outcome based Later Work Program (LWP) for another 6 years to February 28, 2027. The LWP includes the drilling of up to 3 wells and 260 km2 of 3D seismic.
Bengal received special amendment approved for ATP 934 in March 2021 which relinquished 50% of the existing ATP area and extended the term of the ATP by entering into an outcome based Later Work Program (LWP) for another 6 years to February 28, 2027. The LWP includes the drilling of up to 3 wells and 260 km2 of 3D seismic.
ATP 934 Durham Downs East Farmout Block (40% WI)
Bengal entered into an agreement with Santos in July of 2020 to farm-in on a portion of the ATP 934 block. Santos carried the drilling costs of one well to earn a 60% operated interest in the ATP 934 southern farm-out block, which represents 57.8% of the total block post April 2020 relinquishment. On October 14, 2021, Santos completed the drilling of the Legbar-1 exploration well. Santos paid 100% of the costs to drill, plug and abandon the well and has accordingly earned a 60% working interest in 103,760 km2 gross exploration land.
While the Legbar-1 Well did not indicate commercial quantities of hydrocarbons, thick, high quality reservoir sands were encountered in the primary Permian Toolachee formation and in the Jurassic Birkhead zone, with evidence of residual hydrocarbon saturation in both zones. In addition, fluorescence shows and elevated gas readings through the Jurassic lower Birkhead Fm/Top Hutton Sandstone indicate oil has passed through the reservoir, supporting the search for a valid closure to test this play. The findings from the Legbar-1 well will help Bengal refine its exploration targets going forward, both with Santos in the Santos Farm-in Block, and across the balance of ATP 934.
PL 1110 Wareena, PL 1109 Ghina, PL 188 Ramses, PL 411 Karnak, PPL 138 pipeline (100% WI)
As announced in the Bengal press release dated September 12, 2019, the Company acquired a 100% working interest in four PLs and a natural gas pipeline connected to transportation infrastructure into the Eastern Australia Gas Market (collectively, the "Assets"). These non-productive PLs are highly compatible with and in close proximity to ATP 934. Bengal continues to integrate subsurface data from the PLs to enhance the Company's understanding of ATP 934 and to finalize the selection of exploration and appraisal drilling locations.
Included in this program is the reinstatement of two gas wells and an existing gas pipeline to produce raw gas into existing infrastructure. Commercial negotiations, planning and execution of the project are well advanced with materials being delivered and fabrication starting. The company is investing in a proprietary proof of concept arrangement to allow commercial gas production prior to a pipeline connection.
The 100% ownership of the Assets presents an appraisal and development opportunity that will be operated by the Company and is seen to be not only complementary to our proven producing, non-operated Cuisinier asset, but also as a key stepping stone for Bengal's natural gas platform upon which future exploration growth through ATP 934 can be undertaken.
ATP 732 Tookoonooka (100% WI)
In June 2019, the Company applied for an amendment to the LWP for the third term of ATP 732 permit. On October 22, 2019, the Company received approval from the Queensland regulatory authority for an amended LWP for the third, four-year term commencing April 1, 2019 to March 31, 2023. The approved LWP was revised to minimum activities of reprocessing seismic and inversion work with an estimated cost of $50K and geological and geophysical investigation at an estimated cost of $50K during the four-year term.
The Company is currently evaluating the opportunity to stimulate the Caracal-1 well, a 53 API oil discovery in the Wyandra zone. Following stimulation, the well could commence production using the Company's Early Oil Production System with the addition of storage and load-out infrastructure.
The Company is in discussions with potential industry and financial partners to fund some of these oil and gas related activities.
Bengal Energy Ltd. is an international junior oil and gas exploration and production company with assets in Australia. The Company is committed to growing shareholder value through international exploration, production and acquisitions. Bengal's common shares trade on the TSX under the symbol "BNG". Additional information is available at www.bengalenergy.ca.
This news release contains certain forward-looking statements or information ("forward-looking statements") as defined by applicable securities laws that involve substantial known and unknown risks and uncertainties, many of which are beyond Bengal's control. These statements relate to future events or our future performance. All statements other than statements of historical fact may be forward-looking statements. The use of any of the words "plan", "expect", "future", "prospective", "project", "intend", "believe", "should", "would," "anticipate", "estimate", or other similar words or statements that certain events "may" or "will" occur are intended to identify forward-looking statements. The projections, estimates and beliefs contained in such forward-looking statements are based on management's estimates, opinions, and assumptions at the time the statements were made, including assumptions relating to: the impact of economic conditions in North America and Australia and globally; industry conditions; changes in laws and regulations including, without limitation, the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; increased competition; the availability of qualified operating or management personnel; fluctuations in commodity prices, foreign exchange or interest rates; stock market volatility and fluctuations in market valuations of companies with respect to announced transactions and the final valuations thereof; results of exploration and testing activities; and the ability to obtain required approvals and extensions from regulatory authorities. We believe the expectations reflected in those forward-looking statements are reasonable but, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Bengal will derive from them. As such, undue reliance should not be placed on forward-looking statements.
Forward-looking statements contained herein include, but are not limited to, statements regarding:
- The anticipated results of injection of produced formation water at ATP 752;
- The expected 3D seismic controlled Chef exploration drilling project and the timing thereof;
- Bengal's multi-phase water injection scheme, targeted fracture stimulation and the results thereof at ATP 752;
- The expected timing of drilling a well at ATP 934 and Bengal's payment of the tie in costs associated therewith; and
- Bengal's development plans for its four PLs at ATP 934.
The forward-looking statements contained herein are subject to numerous known and unknown risks and uncertainties that may cause Bengal's actual financial results, performance or achievement in future periods to differ materially from those expressed in, or implied by, these forward-looking statements, including but not limited to, risks associated with: the failure to obtain required regulatory approvals or extensions; the failure to satisfy the conditions under farm-in and joint venture agreements; the failure to secure required equipment and personnel; changes in general global economic conditions including, without limitations, the economic conditions in North America and Australia; increased competition; the availability of qualified operating or management personnel; fluctuations in commodity prices, foreign exchange or interest rates; changes in laws and regulations including, without limitation, the adoption of new environmental and tax laws and regulations and changes in how they are interpreted and enforced; the results of exploration and development drilling and related activities; the ability to access sufficient capital from internal and external sources; and stock market volatility. Readers are encouraged to review the material risks discussed in Bengal's annual information form for the year ended March 31, 2021 under the heading "Risk Factors" and in Bengal's management's discussion and analysis for the Q2 of the fiscal year ending March 31,2022 under the heading "Risk Factors". The Company cautions that the foregoing list of assumptions, risks and uncertainties is not exhaustive. The forward-looking statements contained in this news release speak only as of the date hereof and Bengal does not assume any obligation to publicly update or revise them to reflect new events or circumstances, except as may be require pursuant to applicable securities laws.
The following terms used in this news release have the meanings set forth below:
bbl - barrel
bbls - barrels
bbls/d -barrels per day
$/bbl - dollars per barrel
Q1- three months ended June 30
Q2- three months ended September 30
Q4 - three months ended March 31
Within this news release references are made to terms commonly used in the oil and gas industry. Funds from (used in) operations, funds from (used in) operations per share, operating netback, netback per bbl, adjusted net income (loss) and adjusted net income (loss) per share do not have any standardized meaning under IFRS and previous GAAP and are referred to as non-IFRS measures. Funds from (used in) operations per share is calculated based on the weighted average number of common shares outstanding consistent with the calculation of net income (loss) per share. Operating netback includes realized losses on financial instruments. Netback per bbl is calculated by dividing revenue (including realized loss on financial instruments) less royalties, operating expenses by the total production of the Company measured in bbl. Adjusted net income (loss) and adjusted net income (loss) per share are calculated based on Net income (loss) plus unrealized loss (gain) on financial instruments less unrealized foreign exchange loss (gain) and non-cash impairment of non-current assets. The Company's calculation of the non-IFRS measures included herein may differ from the calculation of similar measures by other issuers. Therefore, the Company's non-IFRS measures may not be comparable to other similar measures used by other issuers. Funds from operations is not intended to represent operating profit for the period nor should it be viewed as an alternative to operating profit, net income, cash flow from operations or other measures of financial performance calculated in accordance with IFRS. Non-IFRS measures should only be used in conjunction with the Company's annual audited and interim financial statements. A reconciliation of these measures can be found in the tables on pages 7,14 and 15 of Bengal's management's discussion and analysis for the Q2 of the fiscal year ending March 31, 2022.
Disclosure of Oil and Gas Information
This document discloses test results which are not necessarily indicative of long-term performance or of ultimate recovery.
FOR FURTHER INFORMATION PLEASE CONTACT:
1 Funds from (used in) operations is a non-IFRS measure which is calculated by adding back all non-cash expense deductions to the net loss for the quarter and fiscal year. Funds from (used in) operations per share is a non-IFRS measure calculated as calculated by dividing funds from (used in) operations by weighted average basic and diluted shares outstanding for the periods disclosed. A reconciliation of the measures can be found in the table on page 14 of the December 31, 2021 MD&A.
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