Operational and Financial Summary
Three Months Ended | Year Ended | ||||||
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Operating | |||||||
Average daily production | |||||||
Heavy crude oil (bbls/d) | 468 | 512 | 881 | 465 | 1,112 | ||
Light crude & medium crude oil (bbls/d) | - | 16 | - | 6 | 17 | ||
Natural gas (Mcf/d) | 2,402 | 2,118 | 3,406 | 2,151 | 3,145 | ||
NGLs (bbls/d) | 48 | 38 | 113 | 51 | 89 | ||
Total (boe/d) | 916 | 919 | 1,561 | 880 | 1,742 | ||
Total boe/d per million shares – diluted | 8.4 | 8.4 | 14.3 | 8.1 | 15.9 | ||
Average realized prices | |||||||
Heavy crude oil ($/bbl) | 44.45 | 40.19 | 54.40 | 36.59 | 55.69 | ||
Natural gas ($/Mcf) | 2.87 | 2.45 | 2.70 | 2.43 | 1.73 | ||
NGLs ($/bbl) | 25.72 | 25.83 | 26.64 | 21.32 | 26.75 | ||
Average realized price ($/boe) | 31.56 | 29.87 | 38.50 | 26.74 | 40.50 | ||
$/BOE | |||||||
Petroleum and natural gas sales | 31.56 | 29.87 | 38.50 | 26.74 | 40.50 | ||
Royalties | (2.61) | (2.63) | (4.43) | (2.03) | (4.16) | ||
Operating | (12.75) | (13.85) | (8.63) | (13.27) | (8.25) | ||
Transportation | (1.93) | (2.51) | (2.45) | (2.34) | (3.48) | ||
Operating netback(1) | 14.27 | 10.88 | 22.99 | 9.10 | 24.61 | ||
Realized gain on financial instruments | 1.48 | 0.51 | 0.53 | 4.51 | 0.34 | ||
Operating netback after realized gain on | |||||||
financial instruments(1) | 15.75 | 11.39 | 23.52 | 13.61 | 24.95 | ||
General and administrative | (4.66) | (5.71) | (2.52) | (4.93) | (2.55) | ||
Exploration expense | - | - | - | - | (0.03) | ||
Interest and financing expense (cash) | (1.39) | (1.21) | (0.37) | (0.91) | (0.36) | ||
Adjusted funds flow per boe(1) | 9.70 | 4.47 | 20.63 | 7.77 | 22.01 | ||
Financial ( | |||||||
Petroleum and natural gas sales | 2,659 | 2,526 | 5,531 | 8,615 | 25,757 | ||
Cash flow from operating activities | 206 | 505 | 3,955 | 2,406 | 12,994 | ||
Adjusted funds flow(1) | 818 | 378 | 2,963 | 2,502 | 13,994 | ||
Per share – basic and diluted(1) | 0.01 | - | 0.03 | 0.02 | 0.13 | ||
Net income (loss) | 10,823 | (360) | (56) | (22,313) | 2,215 | ||
Per share – basic and diluted(2) | 0.10 | - | - | (0.20) | 0.02 | ||
Capital expenditures | 105 | 469 | 1,528 | 7,874 | 12,884 | ||
Property acquisitions (dispositions), net | - | (875) | (3,508) | (1,746) | (3,508) | ||
Total capital expenditures, net | 105 | (406) | (1,980) | 6,128 | 9,376 | ||
Net debt(1) | 3,857 | 4,560 | 563 | 3,857 | 563 | ||
Common shares outstanding – basic (000) | 108,921 | 108,921 | 108,921 | 108,921 | 108,921 | ||
(1) | Adjusted funds flow, net debt, operating netback, and operating netback after realized gain on financial instruments are non-GAAP measures that do not have any standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other companies. Refer to the heading entitled "Non-GAAP Measures" included in the "Advisories" section at the end of the MD&A. |
(2) | Basic weighted average shares are used to calculate diluted per share amounts when the Corporation is in a loss position. |
FOURTH QUARTER 2020 REVIEW
Production volumes averaged 916 boe per day in the fourth quarter, consistent with the third quarter of 2020. Production was impacted by one Leduc-Woodbend oil well that was curtailed for most of the quarter due to third-party gas processing restrictions.
Altura's realized heavy oil price increased 11% to
Operating expenses in the fourth quarter were
The Company's operating netback1 averaged
Adjusted funds flow1 was
Altura received
Altura recorded net income of
Altura reduced its net debt1 by
The Company successfully abandoned five inactive wells and reclaimed three wells that were previously abandoned utilizing
2020 REVIEW
2020 will be remembered for the significant challenges to the global economy and energy sector. The COVID-19 induced global economic downturn combined with the actions of
In August, the Company confirmed its revolving operating demand loan (the "Operating Loan") borrowing base at
In 2020, Altura successfully closed two disposition transactions with a private company, divesting of a 2.75% working interest for cash of
These defensive actions were taken to preserve value and safeguard the balance sheet through this pandemic related low oil price period. With the recent strengthening of global economies and commodity price recovery the Company is now well positioned to resume and focus planned activities to capitalize on the depth of its opportunities on its large conventional oil resource with an estimated 400 MMbbls of OOIP2 on Altura's lands.
Altura continued with its Environmental, Social and Governance ("ESG") initiatives in 2020. Starting in
OPERATIONAL UPDATE
In
Altura's current production is estimated at 1,060 boe per day3 based on field estimates from
OUTLOOK
The 2021
Two (1.8 net) new wells at Leduc-Woodbend are planned to be drilled and completed in the summer of 2021 and are scheduled to commence production in July and
Altura's Leduc-Woodbend asset has a well inventory of 47 (36.6 net) booked locations and 104 (67 net) drilling opportunities6 with drilling flexibility at current commodity prices to self-fund growth within cash flow and maintain a strong balance sheet.
Altura expects to close two additional dispositions of a 0.6875% working interest for
While 2020 was primarily a defensive year of survival for many junior oil weighted producers, 2021 is looking to be a year of opportunity. The Altura team is very excited and poised to refocus efforts towards creating value for its shareholders in 2021 and beyond.
2020 RESERVES
During 2020, Altura responded to the unprecedented commodity price weakness and volatility by cutting its planned capital budget in early March and reducing production volumes in April, May and June. The reduction in capital investment, shut-in of production volumes and natural well declines combined to reduce reserves year-over-year.
In addition, a significant reduction in the reserves evaluator's 2020 price forecast compared to 2019 negatively impacted net present values and reserves volumes by reducing well economic limit cut-offs. The evaluator WTI oil price forecast may have been considered reasonable at year-end 2020; however, this forecast has decoupled from current pricing and is now over
YEAR END RESERVES EVALUATION
Altura's year end 2020 reserves were evaluated by independent reserves evaluator
Consistent with 2019, and as per guidance in the Canadian Oil and Gas Evaluation Handbook COGE Handbook ("COGE Handbook"), the McDaniel Report includes all abandonment, decommissioning and reclamation obligations ("ADR"), including all the ADR associated with both active and inactive wells regardless of whether such wells had any attributed reserves.
Unless noted otherwise, reserves included herein are stated on a company gross basis, which is the Company's working interest before deduction of government royalties and excluding any other additional royalty interests. This news release contains several cautionary statements under the heading "Reader Advisory" and throughout the release. In addition to the information contained in this news release, more detailed reserves information will be included in Altura's Annual Information Form for the year ended
Company Gross Reserves as at
The following table summarizes the Company's gross reserve volumes at
Company Gross Reserves(1)(2) | |||||||||
Category | Light | Heavy | Conventional | Natural (Mbbl) | 2020 Oil | 2019 Oil | 2020/ 2019 | ||
Proved | |||||||||
Developed Producing | 164.5 | 562.8 | 3,439.0 | 100.3 | 1,400.8 | 1,754.5 | (20) | ||
Developed Non-Producing | 11.4 | 83.5 | 252.7 | 7.3 | 144.4 | 161.0 | (10) | ||
Undeveloped | - | 2,559.0 | 8,034.1 | 233.0 | 4,131.1 | 4,431.1 | (7) | ||
Total Proved(3) | 176.0 | 3,205.4 | 11,725.8 | 340.6 | 5,676.3 | 6,346.5 | (11) | ||
Total Probable | 67.3 | 2,439.2 | 12,491.8 | 362.8 | 4,951.3 | 4,803.9 | 3 | ||
Total Proved + Probable(3) | 243.3 | 5,644.7 | 24,217.6 | 703.4 | 10,627.6 | 11,150.4 | (5) |
(1) | Gross reserves are Company working interest reserves before royalty deductions |
(2) | Based on the |
(3) | Numbers may not add due to rounding |
Reconciliation of Company Gross Reserves for 2020(1)(2)
Light Crude | Heavy Crude Oil | Conventional | Natural Gas (Mbbl) | Oil Equivalent | ||
Total Proved | ||||||
161.2 | 3,695.0 | 13,052.0 | 315.1 | 6,346.5 | ||
Extensions | 11.4 | - | - | - | 11.4 | |
Technical Revisions | 49.5 | (13.6) | 889.3 | 85.7 | 269.7 | |
Acquisitions | - | - | - | - | - | |
Dispositions | (7.4) | (125.6) | (518.3) | (15.1) | (234.5) | |
Economic Factors | (8.9) | (207.8) | (910.1) | (26.4) | (394.8) | |
Production | (29.8) | (142.6) | (787.1) | (18.6) | (322.1) | |
176.0 | 3,205.4 | 11,725.8 | 340.7 | 5,676.2 | ||
Total Proved + Probable | ||||||
325.4 | 6,031.6 | 25,161.9 | 599.7 | 11,150.4 | ||
Extensions | 14.6 | 509.1 | 1,967.9 | 57.1 | 908.8 | |
Technical Revisions | (38.9) | (250.2) | 297.5 | 135.6 | (104.1) | |
Acquisitions | - | - | - | - | - | |
Dispositions | (38.9) | (250.2) | 297.5 | 135.6 | (104.1) | |
Economic Factors | (18.4) | (311.4) | (1,559.8) | (45.3) | (635.1) | |
Production | (29.8) | (142.6) | (787.1) | (18.6) | (322.1) | |
243.2 | 5,644.6 | 24,217.6 | 703.5 | 10,627.6 | ||
(1) | Gross reserves are Company working interest reserves before royalty deductions |
(2) | Numbers may not add due to rounding |
Technical revisions for heavy crude oil, natural gas and NGLs, in both the Total Proved ("1P") and Total Proved + Probable ("2P") reserves categories, are due to performance deviations and changes in the Leduc-Woodbend production forecast based on higher natural gas production in 2020 than previous year's forecast.
Future Development Costs ("FDC") and Well Schedule
The following is a summary of the estimated FDC and number of wells required to bring 1P and 2P undeveloped reserves on production. Changes in forecast FDC occur annually as a result of drilling activities, acquisition and disposition activities, and changes in capital cost estimates based on improvements in well design and performance, as well as changes in service costs. FDC for 1P undeveloped reserves decreased by $4.1 million compared to year-end 2019 due to a decreased working interest and lower expected drilling and completion cost estimates at Leduc-Woodbend. FDC for 2P undeveloped reserves increased by $0.2 million compared to year-end 2019 due to 2.3 additional net wells in 2020 with decreased expected drilling and completion cost estimates at Leduc-Woodbend.
Total Proved ( | Total Proved Wells(2) Gross (Net) | Total Proved + ( | Total Proved + Gross (Net) | |
2021 | 4,947 | 2 (1.7) | 4,947 | 2 (1.7) |
2022 | 15,111 | 8 (6.6) | 15,261 | 8 (6.6) |
2023 | 21,843 | 11 (9.1) | 26,060 | 13 (10.9) |
2024 | 17,710 | 11 (7.2) | 32,255 | 18 (13.2) |
2025 | - | - | 10,526 | 6 (4.2) |
Total Undiscounted | 59,611 | 32 (24.5) | 89,049 | 47 (36.6) |
(1) | Numbers may not add due to rounding |
(2) | FDC and well counts as per the McDaniel Report and based on the |
The forecasted future net operating income for the next four years from the McDaniel Report based on the
Summary of Before Tax Net Present Value ("NPV") of Future Net Revenue as at
Benchmark oil and NGL prices used are adjusted for quality of oil or NGL produced and for transportation costs. The calculated NPVs are based on the Consultant Average Pricing Forecast at
Before Tax Net Present Value ( | |||||
Discount Rate | |||||
Category | Undiscounted | 5% | 10% | 15% | 20% |
Proved | |||||
Developed Producing | 8,968.9 | 10,540.0 | 10,604.1 | 10,181.4 | 9,630.7 |
Developed Non-Producing | 1,756.0 | 1,562.7 | 1,391.5 | 1,243.6 | 1,116.3 |
Undeveloped | 27,544.7 | 19,555.7 | 13,565.6 | 9,122.3 | 5,822.6 |
Total Proved | 38,269.6 | 31,658.4 | 25,561.2 | 20,547.3 | 16,569.6 |
Total Probable | 60,816.8 | 43,540.0 | 31,887.2 | 23,914.6 | 18,339.6 |
Total Proved + Probable | 99,086.5 | 75,198.4 | 57,448.5 | 44,461.9 | 34,909.1 |
(1) | Based on the |
(2) | Numbers may not add due to rounding |
Price Forecast
The McDaniel Report was based on the Consultant Average Price Forecast at
WTI Crude Oil ($US/bbl) | Western Canadian Select Crude Oil ($CAD/bbl) | Alberta AECO Gas ($CAD/mmbtu) | Foreign | |
2021 | 47.17 | 44.63 | 2.78 | 0.768 |
2022 | 50.17 | 48.18 | 2.70 | 0.765 |
2023 | 53.17 | 52.10 | 2.61 | 0.763 |
2024 | 54.97 | 54.10 | 2.65 | 0.763 |
2025 | 56.07 | 55.19 | 2.70 | 0.763 |
2026 | 57.19 | 56.29 | 2.76 | 0.763 |
2027 | 58.34 | 57.42 | 2.81 | 0.763 |
2028 | 59.50 | 58.57 | 2.87 | 0.763 |
2029 | 60.69 | 59.74 | 2.92 | 0.763 |
2030 | 61.91 | 60.93 | 2.98 | 0.763 |
2031 | 63.15 | 62.15 | 3.04 | 0.763 |
2032 | 64.41 | 63.40 | 3.10 | 0.763 |
2033 | 65.70 | 64.66 | 3.16 | 0.763 |
2034 | 67.01 | 65.96 | 3.23 | 0.763 |
2035 | 68.35 | 67.28 | 3.29 | 0.763 |
thereafter | +2.0%/yr | +2.0%/yr | +2.0%/yr | 0.763 |
Price Forecast Sensitivity
Given the material oil price increase in the first quarter of 2021, Altura prepared a commodity price sensitivity comparing the net present value (before tax, discounted at 10%) of reserves effective
On behalf of the Board of Directors and the Altura management team, we would like to thank our shareholders for their ongoing support.
ABOUT
Altura is a junior oil and gas exploration, development and production company with operations in central Alberta. Altura predominantly produces from the Rex reservoir in the Upper Mannville group and is focused on delivering per share growth and attractive shareholder returns through a combination of organic growth and strategic acquisitions. An updated corporate presentation is available on Altura's website at www.alturaenergy.ca.
READER ADVISORIES
Forward–looking Information and Statements
This press release contains certain forward-looking information and statements within the meaning of applicable securities laws. The use of any of the words "expect", "anticipate", "budget", "forecast", "continue", "estimate", "objective", "ongoing", "may", "will", "project", "should", "believe", "plans", "intends", "strategy" and similar expressions are intended to identify forward-looking information or statements. In particular, but without limiting the foregoing, this press release contains forward-looking information and statements pertaining to:
- Altura's expectation of bringing one shut-in well back on production in
May 2021 ; - Altura's ability to self-fund growth within cash flow and maintain a strong balance sheet;
- plans to close stages 3b and 4 of the previously announced asset disposition on
April 30, 2021 andJune 30, 2021 ; - the 2021 capital expenditure budget;
- forecasted average production and percent growth for 2021.
Statements relating to "reserves", including but not limited to forecasted future net revenue and future development costs, are also deemed to be forward-looking statements, as they involve the implied assessment, based on certain estimates and assumptions, that the reserves described exist in the quantities predicted or estimated and that the reserves can be profitably produced in the future.
The forward-looking information and statements contained in this press release reflect several material factors and expectations and assumptions of Altura including, without limitation:
- the continued performance of Altura's oil and gas properties in a manner consistent with its past experiences
- that Altura will continue to conduct its operations in a manner consistent with past operations;
- the general continuance of current industry conditions;
- the continuance of existing (and in certain circumstances, the implementation of proposed) tax, royalty and regulatory regimes;
- the accuracy of the estimates of Altura's reserves and resource volumes;
- certain commodity price and other cost assumptions;
- the continued availability of oilfield services; and
- the continued availability of adequate debt and equity financing and cash flow from operations to fund its planned expenditures.
Altura believes the material factors, expectations and assumptions reflected in the forward-looking information and statements are reasonable but no assurance can be given that these factors, expectations and assumptions will prove to be correct. To the extent that any forward-looking information contained herein may be considered future oriented financial information or a financial outlook, such information has been included to provide readers with an understanding of management's assumptions used for budgeted and developing future plans and readers are cautioned that the information may not be appropriate for other purposes.
The forward-looking information and statements included in this press release report are not guarantees of future performance and should not be unduly relied upon. Such information and statements involve known and unknown risks, uncertainties and other factors that may cause actual results or events to differ materially from those anticipated in such forward-looking information or statements including, without limitation:
- changes in commodity prices;
- changes in the demand for or supply of Altura's products;
- unanticipated operating results or production declines;
- changes in tax or environmental laws, royalty rates or other regulatory matters;
- changes in development plans of Altura or by third party operators of Altura's properties,
- increased debt levels or debt service requirements;
- inaccurate estimation of Altura's oil and gas reserve and resource volumes;
- limited, unfavorable or a lack of access to capital markets;
- increased costs;
- a lack of adequate insurance coverage;
- the impact of competitors; and
- certain other risks detailed from time to time in Altura's public documents.
The forward-looking information and statements contained in this press release speak only as of the date of this press release, and Altura does not assume any obligation to publicly update or revise them to reflect new events or circumstances, except as may be required pursuant to applicable laws.
Oil and Gas Advisories
Reserves
All reserve references in this press release are "company share reserves". Company share reserves are the Company's total working interest reserves before the deduction of any royalties and including any royalty interests of the Company.
It should not be assumed that the present value of estimated future net revenue presented in the tables above represents the fair market value of the reserves. There is no assurance that the forecast prices and costs assumptions will be attained and variances could be material. The recovery and reserve estimates of Altura's crude oil, natural gas liquids and natural gas reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual crude oil, natural gas and natural gas liquids reserves may be greater than or less than the estimates provided herein.
All future net revenues are estimated using forecast prices, arising from the anticipated development and production of our reserves, net of the associated royalties, operating costs, development costs, and abandonment and reclamation costs and are stated prior to provision for interest and general and administrative expenses. Future net revenues have been presented on a before tax basis. Estimated values of future net revenue disclosed herein do not represent fair market value.
Barrels of Oil Equivalent
The term barrels of oil equivalent ("Boe") may be misleading, particularly if used in isolation. Per Boe amounts have been calculated by using the conversion ratio of six thousand cubic feet (6 mcf) of natural gas to one barrel (1 bbl) of crude oil. The Boe conversion ratio of 6 mcf to 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. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalent of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
Drilling Opportunities
Potential drilling opportunities are internal estimates based on the Corporation's prospective acreage and an assumption as to the number of wells that can be drilled per section based on industry practice and Altura's internal review. Potential drilling opportunities do not have attributed reserves or resources. Potential drilling opportunities have specifically been identified by management as an estimation of our multi-year drilling activities based on evaluation of applicable geologic, seismic, engineering, production and reserves data on prospective acreage and geologic formations. The drilling locations on which we actually drill wells will ultimately depend upon the availability of capital, regulatory approvals, seasonal restrictions, crude oil and natural gas prices, costs, actual drilling results and other factors. While certain of the potential drilling opportunities have been derisked by drilling existing wells in relative close proximity to such potential drilling opportunities, the majority of other potential drilling opportunities are farther away from existing wells where management has less information about the characteristics of the reservoir and therefore there is more uncertainty whether wells will be drilled in such locations, and if drilled there is more uncertainty that such wells will result in additional reserves, resources or production.
Original Oil in Place (OOIP)
For the purpose of this news release, Original Oil in Place ("OOIP") means
Neither the
1 Adjusted funds flow, net debt and operating netback are non-GAAP measures that do not have any standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other companies. Refer to the heading entitled "Non-GAAP Measures" contained within the "Advisories" section of Altura's MD&A | ||||||||||||
2 OOIP is original oil in place. See advisories in this news release | ||||||||||||
3 Consists of 600 bbls/d of heavy crude oil, 52 bbls/d of NGLs and 2,450 Mcf/d of natural gas | ||||||||||||
4 Consists of 40 bbls/d of heavy crude oil, 25 bbls/d of NGLs and 270 Mcf/d of natural gas | ||||||||||||
5 Consists of 465 bbls/d of heavy crude oil, 6 bbls/d of light crude oil, 51 bbls/d of NGLs and 2,151 Mcf/d of natural gas | ||||||||||||
6 See advisories on drilling opportunities in this news release |
SOURCE
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