Cuda Oil and Gas Inc. Announces Third Quarter Financial and Operating Results

Cuda Oil and Gas Inc. (TSXV: CUDA) ("Cuda" or the "Company") announces its financial and operating results for the three and nine months ended September 30, 2020. Cuda's unaudited interim condensed consolidated financial statements and related management's discussion and analysis ("MD&A") as at and for the periods ended September 30, 2020 and 2019, are available under the Company's profile on the SEDAR website at www.sedar.com. Selected financial and operating information for the three and nine months ended September 30, 2020 appear below and should be read in conjunction with the related financial statements and MD&A.

Summary Financial and Operational Results (See "Non-GAAP Measures")



Three months ended
September 30


Nine months ended
September 30


 2020

2019

2020

2019 
OPERATING











Production











Crude oil (bbls/d)
360

264

338

313
Natural gas (mcf/d)
1,386

90

1,500

1,119
Natural gas liquids ("NGLs")(bbls/d) 26

1

28

17
Total (boe/d) 617

280

616

516 


 

 

 

 
Netbacks ($/boe)
 

 

 

 
Average realized price (boe)
37.82

65.00

33.28

50.15
Royalties and production taxes
(10.42)
(20.43)
(9.10)
(13.74)
Operating and transportation (13.31)
(21.90)
(11.62)
(18.06)
Operating netback  14.09

22.67

12.56

18.35 


 

 

 

 
FINANCIAL ($)
 

 

 

 
Revenue
 

 

 

 
Crude oil
1,740,995

1,661,498

4,374,080

5,924,685
Natural gas
322,213

8,297

986,377

874,735
NGLs 84,702

3,091

253,990

260,714 
Total 2,147,910

1,672,886

5,614,447

7,060,134 


 

 

 

 
Adjusted funds flows from (used in) operations
135,596

(1,793,713)
(538,603)
(3,768,124)
Net loss
(3,735,350)
(3,054,961)
(8,205,469)
(31,125,405)
Capital expenditures
1,234,345

2,169,323

9,510,151

6,852,480

 

Third Quarter Highlights

  • Production in Wyoming continues to respond positively to the gas flood project. With the 15 new wells in operation in 2020, third quarter production increased to 360 bbls/d from 307 bbls/d in the second quarter of 2020, an increase of 17% and an increase of 36%, 350 bbls/d versus 264 bbls/d, compared to 2019 third quarter production. Of particular importance, at the William Valentine Injection Pattern where the gas flood is most advanced and estimated and at only 60% of fill-up, wells continue to perform. The BFU 22-27 and BFU 23-27 produced 128 and 131 bbls/d in September 2020, compared to 34 and 31 bbls/d prior to gas injection, respectively.
  • Cuda remains optimistic that opportunities to increase near-term crude oil production from Wyoming can materialize. The Company's project to increase the volume of gas injection to increase 2020 oil production has been slower than anticipated. The continuing impact of COVID-19 has caused WTI price volatility and unstable prices. The realized WTI price in the third quarter improved to $52.45 per bbl from $34.33 per bbl in the second quarter of 2020. However, compared to 2019 third quarter realized WTI price, third quarter 2020 realized WTI price was 24% lower.
  • Realized natural gas prices increased in the third quarter of 2020 to $2.53 per mcf from $2.27 per mcf in the second quarter of 2020. The continuation of stable natural gas prices in 2020, allowed Cuda to continuously produce during higher price environments.
  • Increases in crude oil production from Wyoming and stable AECO gas prices resulted in Cuda increasing its boe/d production in 2020 by 19%, compared to the first nine months of 2019.
  • Cuda's operating netback (see Non-GAAP measures) increased to $14.09/boe for the third quarter, from $7.38/boe for the second quarter of 2020, due to improved crude oil and natural gas prices. Operating netback of $12.56/boe for the first nine months of 2020 was 32% below operating netback for the same period in 2019, reflecting the COVID-19 impact on 2020 crude oil prices.
  • Adjusted funds flows from (used in) operations improved to $135,596 for the three months ended September 30, 2020 from ($1,793,713) for the same period of 2019, and improved to ($538,603) from ($3,768,124) for the nine months ended September 30, 2020 and 2019, respectively.

Financial Position

At September 30, 2020, the Company has a working capital deficiency (including the credit facilities, the convertible debentures and the promissory note) of $61,886,328 and an accumulated deficit of $70,045,144. For the three and nine months ended September 30, 2020, the Company reported net losses of $3,735,350 and $8,205,469 respectively and cash flows from operating activities of $961,383 and $2,308,193, respectively.

The COVID-19 health pandemic continues to cause unprecedented decline in crude oil demand and prices in 2020. The pandemic has negatively impacted the Company's performance in 2020 in spite of increased oil and gas production from both its Wyoming and Alberta assets. With uncertainty related to current COVID-19 circumstances, the Company has elected to focus towards capital expenditures at the Shannon Secondary Recovery Unit in Wyoming, through the Increased Miscible Gas Injection project. The Company estimates capital expenditures of approximately USD $0.73 million for the remainder of 2020, to return the Shannon Reservoir to initial pressures maximizing production response and oil revenue.

At September 30, 2020, the Company had $48.0 million outstanding under the Credit Facilities which matured on July 30, 2020 and remains unpaid which constitutes an event of default under the loan agreement. No waiver has been obtained for the event of default; however, the Company is working with the lender to amend key terms of the loan agreement, including the maturity date.

At September 30, 2020, the Company had $1.6 million outstanding under the convertible debentures which matured on July 21, 2020 and remains unpaid. The debenture holder granted an extension to the notice period to September 23, 2020 to avoid a situation of default. A further extension to the notice period has not been obtained and the Company is working with the debenture holder to amend key terms of the debenture agreement including the maturity date to cure the event of default.

At September 30, 2020, the Company had USD $7.4 million in outstanding joint interest billings and accrued interest with the operator of the Wyoming properties. On July 22, 2020, the Company received formal notification it was in default of its payment obligations under the Unit Operating Agreement. On August 26, 2020, the Company received notification from the operator that it granted the Company a 60-day extension to September 20, 2020 to cure the default. The Company has been unable to pay the outstanding amounts in the time period set out in the notice. A further extension to cure the default has not been obtained. The Company is working with the operator to cure the default.

Further rationalization of assets and/or funding through share issuances, private placements, restructuring of existing or new credit facilities, non-core property sales, increased production from core properties combined with improvements in realized oil and gas prices received and/or a combination of these alternatives will be required to continue as a going concern.

Non-GAAP Measures

This news release contains the terms "adjusted funds flow from (used in) operations", and "operating netback", which do not have standardized meanings prescribed by IFRS and therefore may not be comparable with the calculation of similar measures presented by other issuers.

  • Adjusted funds flow from (used in) operations denotes cash flow from (used in) operating activities as it appears on the Company's consolidated statement of cash flows before decommissioning expenditures, if any, and changes in non-cash operating working capital.
  • Operating netback denotes total revenue less royalty and production tax expenses, and operating and transportation costs calculated on a per boe basis. Management uses operating netback on a per boe basis in operational and capital allocation decisions.
  • BOEs may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of oil equivalent (6 Mcf:1 bbl) is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. As the value ratio between natural gas and crude oil based on the current prices of natural gas and crude oil is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.

Forward-Looking Information

This news release contains forward-looking information. All statements other than statements of historical fact included in this news release are forward-looking statements that involve various risks and uncertainties and are based on forecasts of future operational or financial results, estimates of amounts not yet determinable and assumptions of management. Risk factors that could prevent forward looking statements from being realized include the nature and scope of public health restrictions, the availability of key personnel, market conditions, third party and regulatory approvals, ongoing permitting requirements, the actual results of current exploration and development activities, operational risks, risks associated with drilling and completions, uncertainty of geological and technical data, conclusions of economic evaluations and changes in project parameters as plans continue to be refined as well as future oil and gas prices. Although the Company has attempted to identify important factors that could cause actual results to differ materially, there may be other factors that cause results not to be as anticipated, estimated or intended. There can be no assurance that such statements will prove to be accurate as actual results and future events could differ materially from those anticipated in such statements. Accordingly, readers should not place undue reliance on forward-looking statements. The Company disclaims any intention and has no obligation or responsibility, except as required by law, to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

For further information please contact:
Glenn Dawson - President and Chief Executive Officer
Cuda Oil and Gas Inc. (403) 454-0862

To view the source version of this press release, please visit https://www.newsfilecorp.com/release/68813

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BPH Energy Limited  Quarterly Activities Report

BPH Energy Limited Quarterly Activities Report

Perth, Australia (ABN Newswire) - On 2 August 2022 BPH Energy Limited (ASX:BPH) announced that, following its shareholders' meeting on 21 June 2022 at which shareholders voted unanimously to approve an investment in hydrogen technology company Clean Hydrogen Technologies Corporation ("Clean Hydrogen" or "Vendor" or "Borrower"), BPH and its investee Advent Energy Ltd ("Advent" or "Lender"), together the "Purchasers", settled for the acquisition of a 10% interest in Clean Hydrogen for US$1,000,000 ("Cash Consideration") (8% BPH and 2 % Advent).

The Purchasers had a first right of refusal to invest further in Clean Hydrogen to a maximum of a further US$1,000,000 for an additional 10% interest. The Purchasers loaned a further US$950,000 ("Additional Cash Consideration") under this agreement and the Purchasers and Clean Hydrogen have executed a Loan Conversion Agreement, which once implemented, will enable the conversion of the US$950,000 loan into the relevant Subscription Shares Tranche 2, representing the Purchasers further 9.5% interest in Clean Hydrogen. BPH now has an interest of 15.6% and Advent has an interest of 3.9% interest in Clean Hydrogen.

As at the date of this Quarterly Report, the contemplated securities under the Loan Conversion Agreement have not been issued to the Purchasers, however, the Purchasers have an entitlement to these securities under the relevant Loan Conversion Agreement. For the reasons set out below, BPH will seek approval from its shareholders for the proposed issue of shares in Clean Hydrogen to BPH, in satisfaction of a debt owing from Advent energy Limited to BPH (Debt Forgiveness).

The ASX Listings Committee ('LC') considered the application of Listing Rule 10.1 to the proposed Debt Forgiveness. . The LC resolved that ASX would exercise its discretion such that Listing Rule 10.1 applies to the Debt Forgiveness.

In forming this decision, ASX had regard to the following:

1. In March 2022 ASX advised BPH that, should it seek to increase its shareholding in Advent, whether it be by way of maintaining its current percentage interest in the event Advent undertook a capital raising, increasing its percentage interest, or by way of a debt for equity conversion, BPH must approach ASX regarding the potential application of Listing Rule 10.1.5.

2. In December 2023, Advent lodged a disclosure document with ASIC in the form of an Offer Information Statement for its Entitlement Issue which contained disclosure regarding the discharge of funds loaned to it by BPH in exchange for the issue of equity shares in CHT to BPH. BPH did not approach ASX for determination on the application of Listing Rule 10.1.5 to this transaction.

3. In view of ASX having previously advised BPH to approach ASX in relation to any transactions between itself and Advent including any debt to equity conversion, and BPH having failed to do so in this instance, ASX has exercised its discretion to apply Listing Rule 10.1.5 to the issue of CHT shares to BPH in satisfaction of the debt owing to BPH by Advent. The forgiveness of debt may be a transfer in value from BPH to Advent.

ASX has not been provided with sufficient information to conclude there is no possible transfer in value therefore ASX considers that Listing Rule 10.1.5 applies to the debt conversion/forgiveness.

As a result of ASX's decision to exercise its discretion under Listing Rule 10.1, BPH must seek shareholder approval for the Loan Conversion Agreement dated 10 October 2023 that has been executed between itself, Advent and Clean Hydrogen. The Company is in the process of preparing a Notice of Meeting which will be released as soon as possible. The Company anticipates that the shareholder meeting to approve the Loan Conversion will be held in August 2024.

For clarity, BPH will not and has not increased its shareholding in Advent as a result of the Debt Forgiveness.

Clean Hydrogen have issued 760 share options to BPH and 190 share options to Advent, with an exercise price of USD$3,000 each, exercisable immediately, with the option to convert into shares in Clean Hydrogen expiring ten years from the date of issue. During the Quarter BPH exercised 24 of these options by paying Clean Hydrogen a total exercise price of US$72,000.

The parties acknowledge and agree that the Cash Consideration and Additional Cash Consideration shall be used by Clean Hydrogen to design, build, produce and test a reactor that can produce a minimum of 3.2kgs and as high as 15kgs of hydrogen per hour and to submit at least 2 new patents in an agreed geography, relevant to the production of hydrogen from proprietary technology.

Capital

On 13 May 2024 the Company announced a Placement ("Placement") to raise $1 million by the issue of 50,000,000 fully paid ordinary shares at an issue price of $0.02 per share together with a 1 for 2 free listed option, being 25,000,000 listed options with an exercise price of $0.03 each and expiry 30 September 2024. The Placement offer price of $0.02 per share represents a 16.7% discount to BPH's closing price of $0.024 per share on Thursday, 9 May 2024, and a 16.7 % discount to the 10-day VWAP of $0.024 per share.

The Placement proceeds are proposed to be used as follows: (i) $0.75 million - funding for exploration and development of oil and gas investments. (ii) $0.1 million - for working capital, including costs of the offer; and (iii) $0.15 million - funding for Cortical Dynamics. In addition, a total of 12,000,000 listed options with an exercise price of $0.03 each and expiry 30 September 2024 (BHPOB) were issued to the joint Lead Managers (Oakley Capital Partners Pty Limited and Sixty-Two Capital) for the Placement.

Significant activities by the Company's investees' during the June 2024 quarter were as follows:

Advent Energy Limited ("Advent") (BPH 35.8% direct interest)

PEP 11 Permit

Advent Energy Limited's (BPH 35.8% direct interest) 100% subsidiary Asset Energy Pty Ltd is a participant in the PEP11 Joint Venture with partner Bounty Oil and Gas NL (ASX:BUY). PEP 11 interests are:

Advent Energy 85 % / Bounty Oil and Gas 15%

Asset continues to progress the joint venture's applications for the variation and suspension of work program conditions and related extension of PEP-11. This application follows from the fact that in February 2023 a decision by the previous Commonwealth-NSW Joint Authority to refuse the application was quashed by the Federal Court of Australia. Asset has provided additional updated information to the Commonwealth-NSW Joint Authority and the National Offshore Petroleum Titles Administrator ("NOPTA") in relation to its applications.

On 9 October 2023 NOPTA updated their website whereby the NEATS Public Portal Application Tracking has been updated to show Asset Energy's applications' status is now 'Under Assessment'.

The Company understands that the next step in the application process is for the Joint Authority to make its decision on Asset Energy's applications.

While the applications for the variation and suspension of work program conditions and related extension of PEP-11 are being considered by NOPTA, Asset is investigating the availability of a mobile offshore drilling unit to drill the proposed Seablue-1 well on the Baleen prospect which would take approximately thirty-five days to complete. Asset is in communication with drilling contractors and other operators who have recently contracted rigs for work in the Australian offshore.

The Joint Authority decision is a routine administrative decision. Any future authorisation related to drilling will require environmental approvals. Any issues around community or environmental impacts should be transparently managed by the designated independent expert regulator.

Asset have engaged Klarite Pty Ltd (Klarite) to initiate environmental management of the Seablue1 exploration well, due to be drilled in PEP 11, pending the current application for licence variation, suspension and extension (Application), regulatory approvals and rig availability. Klarite are a Perth based turnkey environmental consultancy specialising in offshore development in Australia, who recently prepared a detailed Environmental Approvals Strategy for the Seablue-1 exploration drilling activity for Asset. Due to the critical need for new domestic supplies of gas as stated in the Federal Government's Future Gas Strategy (see below), Asset have decided to commence work necessary for environmental approvals in advance of the PEP 11 licence Application approval, in order to be prepared to drill the Seablue-1 well as soon as possible thereafter. Klarite will develop an Environmental Management process which will define Asset's consultation and negotiation basis with relevant persons and assess environmental impacts.

The Federal Government Future Gas Strategy (FGS) and supporting documents were released by Minister for Resources Madeleine King on 9 May 2024. The FGS confirms that that gas will have a role to play in the transition to net zero by 2050 and beyond. The FGS states that exploration and development should focus on optimising discoveries and infrastructure in producing basins where gas will be proximal to where it is needed and will be lower cost than relying on LNG imports.

Offshore gas exploration in Australia has been undertaken safely and environmentally responsibly for more than 50 years.

The fact remains that NSW and Australia more broadly face a gas supply shortfall within the next three years, and gas will play a vital role in the clean energy transition.

PEP-11 continues in force and the Joint Venture is in compliance with the contractual terms of PEP11 with respect to such matters as reporting, payment of rents and the various provisions of the Offshore Petroleum and Greenhouse Gas Storage Act 2006 (Cth).

RL1 (Norther Territory)

On 3 May 2024 the Company announced that Advent has been offered a renewal of Retention Licence 1 (RL1) by the Northern Territory Government for a five-year term which it has accepted.

Advent, through its wholly owned subsidiary Onshore Energy Pty Ltd, holds a 100 % interest in RL1 and is operator of the Retention Licence in the onshore Bonaparte Basin in northern Australia. The Bonaparte Basin is a highly prospective, petroliferous basin, with significant prospective potential for reserves of oil and gas. Most of the basin is located offshore, covering 250,000 square kilometres, compared to just over 20,000 square kilometres onshore and is recognized as one of Australia's most prolific offshore hydrocarbon producing basin (after the Northern Carnarvon and Gippsland basins). Retention Licence RL1 in the Northern Territory is 166 square kilometres in area and covers the Weaber Gas Field, originally discovered in 1985.

Cortical Dynamics Limited ("Cortical") (BPH 16.4% direct interest)

Investee Cortical Dynamics Limited is an Australian based medical device neurotechnology company that is developing BARM(TM), an industry leading EEG (electrical activity) brain function monitor. BARM(TM) is being developed to better detect the effect of anaesthetic agents on brain activity under a general operation, aiding anaesthetists in keeping patients optimally anaesthetised, and complemented by CORDYAN(TM) (Cortical Dynamics Analytics), a proprietary deep learning system/App focusing on anaesthesiology.

The Australian manufactured and designed, electroencephalographically based (EEG-based), BARM(TM) system is configured to efficiently image and display complex information related to the clinically relevant state of the brain. When commercialized the BARM(TM) system will be offered on a stand-alone basis or integrated into leading brand operating room monitors as "plug and play" option.

There were no significant activities in Cortical to report during the Quarter.

Item 1 and 2 details of payments to / receipts from related parties (Appendix 4C)

Line 6.1 outflow of $59,000: $29,470 paid to directors as remuneration and net $29,958 fees paid to Grandbridge Limited.

Line 6.2 outflow of $801,000: Loans to the following companies:
Advent Energy Limited $405,000 paid
Cortical Dynamics Limited: $400,000 paid
Grandbridge Limited: $4,000 received

*To view the full Quarterly Report, please visit:
https://abnnewswire.net/lnk/KQ75D046



About BPH Energy Limited:

BPH Energy Limited (ASX:BPH) is an Australian Securities Exchange listed company developing biomedical research and technologies within Australian Universities and Hospital Institutes.

The company provides early stage funding, project management and commercialisation strategies for a direct collaboration, a spin out company or to secure a license.

BPH provides funding for commercial strategies for proof of concept, research and product development, whilst the institutional partner provides infrastructure and the core scientific expertise.

BPH currently partners with several academic institutions including The Harry Perkins Institute for Medical Research and Swinburne University of Technology (SUT).



Source:
BPH Energy Limited

News Provided by ABN Newswire via QuoteMedia

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