Alvopetro Announces 2022 Year End Reserves with a 17% Increase in 2P NPV Before Tax
CALGARY, AB, Feb. 28, 2023 /CNW/ - Alvopetro Energy Ltd. (TSXV: ALV) (OTCQX: ALVOF) announces our reserves as at December 31, 2022 with total proved plus probable ("2P") reserves of 9.0 MMboe and a before tax net present value discounted at 10% of $348.2 million. 2P reserve additions replaced 132% of 2022 production. 2P reserve volumes increased by 3%, despite 0.9 MMboe of production in 2022, due to reserve additions associated mainly with two additional Murucututu development locations (previously included in contingent resources). The before tax net present value of our 2P reserves (discounted at 10%) increased by 17% from December 31, 2021, due to reserve additions and increases in forecasted natural gas prices. Alvopetro also announces the December 31, 2022 assessment of the Company's Murucututu natural gas resource with risked best estimate contingent resource of 2.9 MMboe and risked best estimate prospective resource of 12.5 MMboe. The Murucututu natural gas contingent and prospective resource values (risked best estimate net present value before tax, discounted at 10%) are $62.2 million and $259.1 million, respectively. The reserves and resources data set forth herein is based on an independent reserves and resources assessment and evaluation prepared by GLJ Ltd. ("GLJ") dated February 27, 2023 with an effective date of December 31, 2022 (the "GLJ Reserves and Resources Report").
All references herein to $ refer to United States dollars, unless otherwise stated.
December 31, 2022 GLJ Reserves and Resource Report Highlights
- 2P net present value before tax discounted at 10% increased 17% to $348.2 million.
- Proved reserves ("1P") decreased 12% to 3.9 MMboe and 2P reserves increased 3% to 9.0 MMboe after 0.9 MMboe of production in 2022.
- 2P production replacement ratio(1) of 132%.
- 2P F&D costs(1) estimated at $28.66/boe.
- 2P recycle ratio(1) estimated at 2.1 times.
- 2P Net Asset Value(1) of CAD$13.56/share ($9.99/share) before any potential from contingent or prospective resources.
- Risked best estimate contingent resource of 2.9 MMboe (NPV10 $62.2 million) and risked best estimate prospective resource of 12.5 MMboe (NPV10 $259.1 million).
Corey Ruttan, President and Chief Executive Officer, commented:
"Our 2022 year-end reserves and resource evaluations highlight the continued strong profitability from our Caburé natural gas field and the long-term potential of our Murucututu project. The increase in forecasted cash flows reflects the impact of reserve additions associated with our near-term development plans on our Murucututu asset and increases in forecasted natural gas prices under our long-term gas sales agreement. Our 2023 capital program is focused on lower risk development opportunities including accelerated activity on our Murucututu asset targeting the long-term natural gas potential of this field."
(1) |
Refer to the sections entitled "Oil and Natural Gas Advisories – Other Metrics" and "Non-GAAP and Other Financial Measures" for additional disclosures and assumptions used in calculating production replacement ratio, F&D costs, recycle ratio, net asset value and net asset value per share. |
December 31, 2022 Gross Reserve and Gross Resource Volumes: (1)(2)(3)(4)(5)(6)
December 31, 2022 Reserves (Gross) |
Total Proved (1P) |
Total Proved plus Probable (2P) |
Total Proved plus Probable plus Possible (3P) |
(Mboe) |
(Mboe) |
(Mboe) |
|
Caburé Natural Gas Field |
2,505 |
4,146 |
5,637 |
Murucututu Natural Gas Field |
1,232 |
4,584 |
8,149 |
Bom Lugar Oil Field |
148 |
269 |
542 |
Mãe-da-lua Oil Field |
25 |
38 |
55 |
Total Company Reserves |
3,909 |
9,037 |
14,382 |
See 'Footnotes' section at the end of this news release |
|||
December 31, 2022 Murucututu Resources (Gross) |
Low Estimate |
Best Estimate |
High Estimate |
(Mboe) |
(Mboe) |
(Mboe) |
|
Risked Contingent Resource Risked Prospective Resource |
2,639 6,774 |
2,907 12,501 |
4,228 18,481 |
See 'Footnotes' section at the end of this news release |
|||
Net Present Value Before Tax Discounted at 10%:(1)(2)(3)(4)(5)(6)(7)(8)
Reserves |
1P |
2P |
3P |
($000s) |
($000s) |
($000s) |
|
Caburé Property |
134,023 |
211,924 |
270,744 |
Murucututu Property |
33,034 |
126,946 |
222,675 |
Other Properties |
3,693 |
9,306 |
18,542 |
Total Company |
170,751 |
348,176 |
511,961 |
See 'Footnotes' section at the end of this news release |
|||
Murucututu Resource |
Low Estimate |
Best Estimate |
High Estimate |
($000s) |
($000s) |
($000s) |
|
Risked Contingent Resource Risked Prospective Resource |
58,892 128,581 |
62,218 259,119 |
92,105 383,605 |
See 'Footnotes' section at the end of this news release |
|||
Following the December 31, 2022 reserves evaluation, based on the before tax net present value of Alvopetro's 2P reserves (discounted at 10%), our total 2P net asset value is $362.9 million; CAD$13.56 per common share outstanding. Our 2P net asset value of $362.9 million is before including the before tax net present value (discounted at 10%) of our risked best estimate risked contingent resource of $62.2 million and our risked prospective resource of $259.1 million from the Murucututu natural gas field.
Net Asset Value (in $000s, other than per share amounts) |
1P |
2P |
3P |
Before Tax Net Present Value, Discounted at 10% ($000s) |
170,751 |
348,176 |
511,961 |
Net working capital – as at December 31, 2022(1)(2) |
14,698 |
14,698 |
14,698 |
Total Net Asset Value(2),(3)(4) |
185,449 |
362,874 |
526,659 |
CAD per basic share(5) |
6.93 |
13.56 |
19.69 |
(1) |
Working capital is estimated as of December 31, 2022 and based on unaudited financial information and is subject to change. See "Unaudited Financial Information" in this press release. |
(2) |
Non-GAAP measure. See 'Non-GAAP and Other Financial Measures' in this news release for additional details. |
(3) |
Alvopetro has reflected the contractual obligations pursuant to our September 2018 Gas Treatment Agreement with Enerflex, including the equipment rental component of the agreement which is treated as a right of use asset and reflected as a capital lease obligation on our financial statements. As the future capital lease payments reduce the forecasted future net revenue in all reserves categories, the capital lease obligation as reflected on the Company's financial statements has not been included in the table above. |
(4) |
The net asset value reflected above includes the present value of before tax cash flows from the Company's reserves only. No amounts have been included with respect to contingent or prospective resource volumes. |
(5) |
Converted to Canadian dollars ("CAD") based on the exchange rate on February 27, 2023. The per share calculation is computed based on 36.3 million common shares outstanding as of February 27, 2023. |
GLJ employed the following pricing and inflation rate assumptions as of January 1, 2023 in the GLJ Reserves and Resources Report in estimating reserves and resources data using forecast prices and costs.
Year |
Brent Blend Crude Oil FOB North Sea ($/Bbl) |
National Balancing Point (UK) ($/MMBtu) |
NYMEX Henry Hub Near Month Contract ($/MMBtu) |
Alvopetro-Bahiagas Gas Contract $/MMBtu (Current Year) |
Alvopetro-Bahiagas Gas Contract $/MMBtu (Previous Year) |
Change from prior year |
2023 |
80.00 |
28.00 |
4.71 |
10.61 |
10.09 |
5 % |
2024 |
80.50 |
24.15 |
4.50 |
10.96 |
9.86 |
11 % |
2025 |
81.50 |
20.00 |
4.27 |
10.79 |
9.00 |
20 % |
2026 |
82.00 |
14.00 |
4.35 |
11.01 |
8.89 |
24 % |
2027 |
82.53 |
10.75 |
4.44 |
11.12 |
8.99 |
24 % |
2028 |
84.14 |
10.98 |
4.53 |
10.75 |
9.15 |
17 % |
2029 |
85.85 |
11.20 |
4.62 |
10.73 |
9.33 |
15 % |
2030 |
87.58 |
11.43 |
4.71 |
10.88 |
9.52 |
14 % |
2031 |
89.32 |
11.66 |
4.80 |
11.09 |
9.71 |
14 % |
2032* |
91.11 |
11.89 |
4.90 |
11.30 |
9.90 |
14 % |
*Escalated at 2% per year thereafter |
As of February 1, 2023, Alvopetro's contracted natural gas price under the terms of our long-term gas sales agreement is based on the ceiling price within the contract and is forecasted to remain at the ceiling price until 2027. The ceiling price incorporates assumed US inflation of 3% in 2023 and 2% thereafter.
The GLJ Reserves and Resources Report has been prepared in accordance with the standards contained in the Canadian Oil and Gas Evaluation Handbook ("COGEH") that are consistent with the standards of National Instrument 51-101 ("NI 51-101"). GLJ is a qualified reserves evaluator as defined in NI 51-101. The GLJ Reserves and Resources Report was an evaluation of all reserves of Alvopetro including our Caburé and Caburé Leste natural gas fields (collectively referred to as our Caburé natural gas field), our Murucututu natural gas project (previously referred to as Gomo), as well as our Bom Lugar and Mãe-da-lua oil fields. The GLJ Reserves and Resources Report also includes an evaluation of the gas resources of our Murucututu natural gas. In addition to the reserves assigned to our two existing Murucututu wells (197-1 and 183-1) and four additional development locations, contingent resource was assigned to the area in proximity to our existing Murucututu reserves, deemed to be discovered. The area mapped by 3D seismic west and north of the area defined as contingent was assigned prospective resource. Additional reserves and resources information as required under NI 51-101 will be included in the Company's Annual Information Form for the 2022 fiscal year which will be filed on SEDAR by April 30, 2023.
Summary of Reserves (1)(2)(3)
Light & Medium Oil |
Conventional Natural |
Natural Gas Liquids |
Oil Equivalent |
|||||
Company Gross |
Company |
Company |
Company |
Company |
Company |
Company |
Company |
|
(Mbbl) |
(Mbbl) |
(MMcf) |
(MMcf) |
(Mbbl) |
(Mbbl) |
(Mboe) |
(Mboe) |
|
Proved |
||||||||
Producing |
- |
- |
16,291 |
15,435 |
223 |
211 |
2,938 |
2,784 |
Developed Non-Producing |
25 |
22 |
- |
- |
- |
- |
25 |
22 |
Undeveloped |
148 |
140 |
4,040 |
3,787 |
125 |
117 |
946 |
888 |
Total Proved |
173 |
162 |
20,332 |
19,222 |
348 |
328 |
3,909 |
3,694 |
Probable |
133 |
125 |
26,278 |
24,760 |
614 |
578 |
5,128 |
4,830 |
Total Proved plus Probable |
306 |
287 |
46,610 |
43,982 |
962 |
906 |
9,037 |
8,524 |
Possible |
290 |
273 |
26,499 |
24,938 |
639 |
600 |
5,345 |
5,029 |
Total Proved plus Probable plus |
596 |
561 |
73,108 |
68,919 |
1,601 |
1,506 |
14,382 |
13,553 |
See 'Footnotes' section at the end of this news release |
Summary of Before Tax Net Present Value of Future Net Revenue - $000s (1)(2)(3)(7)(8)
Undiscounted |
5 % |
10 % |
15 % |
20 % |
||
Proved |
||||||
Producing |
175,155 |
159,578 |
146,947 |
136,806 |
128,400 |
|
Developed Non-Producing |
454 |
453 |
446 |
437 |
427 |
|
Undeveloped |
45,093 |
31,327 |
23,358 |
18,120 |
14,394 |
|
Total Proved |
220,702 |
191,358 |
170,751 |
155,363 |
143,221 |
|
Probable |
380,085 |
240,807 |
177,426 |
140,449 |
115,665 |
|
Total Proved plus Probable |
600,787 |
432,165 |
348,176 |
295,813 |
258,886 |
|
Possible |
441,963 |
239,781 |
163,785 |
124,468 |
99,884 |
|
Total Proved plus Probable plus Possible |
1,042,750 |
671,946 |
511,961 |
420,280 |
358,770 |
|
See 'Footnotes' section at the end of this news release |
Summary of After Tax Net Present Value of Future Net Revenue – $000s (1)(2)(3)(7)(8)
Undiscounted |
5 % |
10 % |
15 % |
20 % |
||
Proved |
||||||
Producing |
156,035 |
143,855 |
133,178 |
124,356 |
116,937 |
|
Developed Non-Producing |
383 |
384 |
380 |
373 |
365 |
|
Undeveloped |
35,724 |
25,247 |
18,962 |
14,727 |
11,662 |
|
Total Proved |
192,142 |
169,486 |
152,520 |
139,456 |
128,964 |
|
Probable |
289,379 |
190,348 |
142,952 |
114,291 |
94,583 |
|
Total Proved plus Probable |
481,521 |
359,834 |
295,473 |
253,747 |
223,547 |
|
Possible |
329,908 |
187,660 |
131,716 |
101,493 |
82,000 |
|
Total Proved plus Probable plus Possible |
811,428 |
547,494 |
427,189 |
355,240 |
305,546 |
|
See 'Footnotes' section at the end of this news release |
Future Development Costs (1)(2)(3)(7)(8)
The table below sets out the total development costs deducted in the estimation of future net revenue attributable to proved reserves, proved plus probable reserves and proved plus probable plus possible reserves (using forecast prices and costs), by field, in the GLJ Reserves and Resources Report. Total development costs include capital costs for drilling and facility and pipeline expenditures but excludes abandonment and reclamation costs.
Under each reserve category, Alvopetro has elected to reflect 100% of the contractual obligations pursuant to our Gas Treatment Agreement with Enerflex, including all operating, capital, and related financing costs for the full duration of the agreement. These costs are mainly attributable to the Caburé field and also represent the majority of the future development costs for the Caburé field in the table below. The future costs associated with equipment rental are also reflected as a capital lease obligation on our financial statements. Also included in future development costs for the Caburé field are two step-out wells and expansion of the unit facilities.
The future development costs for the Murucututu field in the proved category are for two development locations in the field and the stimulation of the 197(1) well. In the probable and possible categories, there are future development costs for two additional development locations. Also included in the Murucututu future development costs for all reserve categories are a portion of the anticipated contractual obligations associated with the expansion of the gas treatment facility. The future development costs for Bom Lugar in the proved category include costs for one development well and facilities upgrade. A second development well is included in the future development costs for the possible category for Bom Lugar. Future development costs at the Mãe-da-lua field relate to a stimulation of the existing producing well.
$000s, Undiscounted |
2023 |
2024 |
2025 |
2026 |
2027 |
Remaining |
Total |
|
Proved |
||||||||
Caburé Natural Gas Field |
4,539 |
1,730 |
6,676 |
- |
- |
- |
12,944 |
|
Murucututu Gas Field |
8,480 |
6,295 |
420 |
- |
- |
- |
15,195 |
|
Bom Lugar Oil Field |
3,910 |
- |
- |
- |
- |
- |
3,910 |
|
Mãe-da-lua Oil Field |
540 |
- |
- |
- |
- |
- |
540 |
|
Total Proved |
17,469 |
8,025 |
7,096 |
- |
- |
- |
32,590 |
|
Proved Plus Probable |
||||||||
Caburé Natural Gas Field |
4,539 |
1,730 |
1,730 |
1,730 |
4,409 |
- |
14,138 |
|
Murucututu Gas Field |
14,680 |
13,190 |
420 |
420 |
420 |
- |
29,130 |
|
Bom Lugar Oil Field |
4,810 |
- |
- |
- |
- |
- |
4,810 |
|
Mãe-da-lua Oil Field |
540 |
- |
- |
- |
- |
- |
540 |
|
Total Proved Plus Probable |
24,569 |
14,920 |
2,150 |
2,150 |
4,829 |
- |
48,618 |
|
Proved Plus Probable Plus Possible |
||||||||
Caburé Natural Gas Field |
4,539 |
1,730 |
1,730 |
1,730 |
1,730 |
3,622 |
15,080 |
|
Murucututu Gas Field |
14,680 |
13,190 |
420 |
420 |
420 |
840 |
29,970 |
|
Bom Lugar Oil Field |
9,650 |
- |
- |
- |
- |
- |
9,650 |
|
Mãe-da-lua Oil Field |
540 |
- |
- |
- |
- |
- |
540 |
|
Total Proved Plus Probable Plus Possible |
29,409 |
14,920 |
2,150 |
2,150 |
2,150 |
4,462 |
55,240 |
|
See 'Footnotes' section at the end of this news release |
Reconciliation of Alvopetro's Gross Reserves (Before Royalty) (1)(2)(3)(8)
Proved |
Probable |
Proved Plus Probable |
Possible (Mboe) |
Proved plus Probable plus Possible (Mboe) |
|
December 31, 2021 |
4,421 |
4,316 |
8,737 |
4,639 |
13,376 |
Extensions |
182 |
808 |
990 |
990 |
1,980 |
Technical Revisions |
239 |
4 |
242 |
(283) |
(41) |
Economic Factors |
1 |
- |
1 |
(1) |
- |
Production |
(933) |
- |
(933) |
- |
(933) |
December 31, 2022 |
3,909 |
5,128 |
9,037 |
5,345 |
14,382 |
See 'Footnotes' section at the end of this news release |
Summary of Unrisked Company Gross Contingent Resources (1)(2)(5)(6)
Development Pending Economic Contingent Resources |
Low Estimate |
Best Estimate |
High Estimate |
Conventional natural gas (MMcf) |
14,800 |
16,302 |
23,711 |
Natural gas liquids (Mbbl) |
457 |
504 |
733 |
Oil equivalent (Mboe) |
2,924 |
3,221 |
4,684 |
See 'Footnotes' section at the end of this news release. |
Summary of Before Tax Net Present Value of Future Net Revenue of Unrisked Contingent Resources- $000s (1)(2)(5)(6)(7)(8)
Undiscounted |
5 % |
10 % |
15 % |
20 % |
|
Low Estimate |
197,575 |
103,633 |
65,254 |
45,386 |
33,458 |
Best Estimate |
228,494 |
112,051 |
68,940 |
47,609 |
35,054 |
High Estimate |
367,713 |
168,900 |
102,055 |
70,600 |
52,486 |
See 'Footnotes' section at the end of this news release. |
The GLJ Contingent Resource Report for Murucututu assumes capital deployment starting in 2024 for the drilling of wells with total project costs of $19.1 million and first commercial production in 2024. The information presented herein is based on company net project development costs. The recovery technology assumed for purposes of the estimate is based on established technologies utilized repeatedly in the industry.
There can be no certainty that the project will be developed on the timelines discussed herein. The project is based on a pre-development study. Development of the project is dependent on several contingencies as further described in this news release. Significant positive factors relevant to the estimate include existing production in close proximity, proximity to infrastructure, existing long-term gas sales agreement and corporate commitment to the project. Significant negative factors relevant to the estimate include reservoir performance and the economic viability of the project (with sensitivity to low commodity prices), access to and amount of capital required to develop resources at an acceptable cost, and regulatory approvals for planned activities including stimulations and new infrastructure developments.
Summary of Development Pending Risked Company Gross Contingent Resources(1)(2)(5)(6)
The GLJ Reserves and Resources Report estimates the Chance of Development as the product of two main contingencies associated with the project development, which are: 1) the probability of corporate sanctioning, which GLJ estimates at 95%; 2) the probability of finalization of a development plan, which GLJ estimates at 95%. The product of these two contingencies is 90%. As there is no risk related to discovery, the Chance of Commerciality for the contingent resource is therefore 90% which is the risk factor that has been applied to the Development Risked company gross contingent resources and the net present value figures reported below.
Low Estimate |
Best Estimate |
High Estimate |
|
Conventional natural gas (MMcf) |
13,357 |
14,713 |
21,399 |
Natural gas liquids (Mbbl) |
413 |
455 |
661 |
Oil equivalent (Mboe) |
2,639 |
2,907 |
4,228 |
See 'Footnotes' section at the end of this news release. |
Summary of Development Pending Risked Before Tax Net Present Value of Future Net Revenue of Contingent Resources- $000s(1)(5)(6)(7)(8)
Undiscounted |
5 % |
10 % |
15 % |
20 % |
|
Low Estimate |
178,311 |
93,529 |
58,892 |
40,961 |
30,196 |
Best Estimate |
206,216 |
101,126 |
62,218 |
42,967 |
31,636 |
High Estimate |
331,861 |
152,432 |
92,105 |
63,716 |
47,369 |
See 'Footnotes' section at the end of this news release. |
Summary of Unrisked Company Gross Prospective Resources (1)(2)(4)(6)
Prospective Resources |
Low |
Best |
High |
Conventional natural gas (MMcf) |
42,273 |
78,017 |
115,335 |
Natural gas liquids (Mbbl) |
1,306 |
2,410 |
3,563 |
Oil equivalent (Mboe) |
8,351 |
15,413 |
22,786 |
See 'Footnotes' section at the end of this news release. |
Summary of Before Tax Net Present Value of Future Net Revenue of Unrisked Prospective Resources - $000s (1)(4)(6)(7)(8)
Undiscounted |
5 % |
10 % |
15 % |
20 % |
|
Low Estimate |
608,512 |
281,759 |
158,531 |
99,430 |
66,486 |
Best Estimate |
1,261,728 |
560,612 |
319,476 |
207,106 |
144,368 |
High Estimate |
1,972,455 |
839,098 |
472,958 |
307,587 |
216,260 |
See 'Footnotes' section at the end of this news release. |
The GLJ Reserves and Resources Report for Murucututu prospective resources assumes capital deployment starting in 2025 for the drilling of wells, expansion of field facilities, and additional pipeline capacity, with total project costs of $70.0 million and first commercial production in 2025. The information presented herein is based on company project development costs. The recovery technology assumed for purposes of the estimate is based on established technologies utilized repeatedly in the industry.
There can be no certainty that the project will be developed on the timelines discussed herein. Development of the project is dependent on several contingencies as further described in this news release. The project is based on a conceptual study. Significant positive factors relevant to the estimate include existing production in close proximity, proximity to infrastructure, existing long-term gas sales agreement and corporate commitment to the project. Significant negative factors relevant to the estimate include reservoir performance and the economic viability of the project (with sensitivity to low commodity prices), access to and amount of capital required to develop resources at an acceptable cost, and regulatory approvals for planned activities including stimulations and new infrastructure developments.
Summary of Development Risked Company Gross Prospective Resources(1)(2)(4)(6)
The GLJ Reserves and Resources Report estimates the Chance of Commerciality as the product between the Chance of Discovery and the Chance of Development. The Chance of Discovery of the prospective resources has been assessed at 90%, while the Chance of Development has been assessed as the same as for the Contingent Resources described above at 90%. The resulting Chance of Commerciality is 81%, which has been applied to the company gross unrisked prospective resources and the net present value figures reported below.
Low |
Best |
High |
|
Conventional natural gas (MMcf) |
34,286 |
63,278 |
93,546 |
Natural gas liquids (Mboe) |
1,059 |
1,955 |
2,890 |
Oil equivalent (Mboe) |
6,774 |
12,501 |
18,481 |
See 'Footnotes' section at the end of this news release. |
Summary of Development Risked Before Tax Net Present Value of Future Net Revenue of Prospective Resources- $000s(1)(4)(6)(7)(8)
Undiscounted |
5 % |
10 % |
15 % |
20 % |
|
Low Estimate |
493,550 |
228,528 |
128,581 |
80,645 |
53,925 |
Best Estimate |
1,023,358 |
454,700 |
259,119 |
167,979 |
117,094 |
High Estimate |
1,599,813 |
680,573 |
383,605 |
249,477 |
175,403 |
See 'Footnotes' section at the end of this news release. |
Alvopetro anticipates announcing its 2022 fourth quarter and year-end results on March 21, 2023 after markets close and will host a live webcast to discuss the results at 9:00 am Mountain time, on March 22, 2023. Details for joining the event are as follows:
DATE: March 22, 2023
TIME: 9:00 AM Mountain/11:00 AM Eastern
LINK: https://us06web.zoom.us/j/83279531812
DIAL-IN NUMBERS: https://us06web.zoom.us/u/kcfqlsznW
WEBINAR ID: 832 7953 1812
The webcast will include a question and answer period. Online participants will be able to ask questions through the Zoom portal. Dial-in participants can email questions directly to [email protected].
Alvopetro's updated corporate presentation is available on our website at:
http://www.alvopetro.com/corporate-presentation.
FOOTNOTES
(1) |
References to Company Gross reserves or Company Gross Resources means the total working interest share of remaining recoverable reserves or resources held by Alvopetro before deductions of royalties payable to others and without including any royalty interests held by Alvopetro. |
(2) |
The tables above are a summary of the reserves of Alvopetro and the net present value of future net revenue attributable to such reserves as evaluated in the GLJ Reserves and Resources Report based on forecast price and cost assumptions. The tables summarize the data contained in the GLJ Reserves and Resources Report and as a result may contain slightly different numbers than such report due to rounding. Also due to rounding, certain columns may not add exactly. |
(3) |
Possible reserves are those additional reserves that are less certain to be recovered than probable reserves. There is a 10% probability that the quantities actually recovered will equal or exceed the sum of proved plus probable plus possible reserves. |
(4) |
Prospective Resources are defined in the COGE Handbook as those quantities of petroleum estimated, as of a given date, to be potentially recoverable from undiscovered accumulations by application of future development projects. Prospective resources have both an associated chance of discovery and a chance of development. There is no certainty that any portion of the prospective resources will be discovered and even if discovered, there is no certainty that it will be commercially viable to produce any portion. Prospective Resources are further subdivided in accordance with the level of certainty associated with recoverable estimates assuming their discovery as described in footnote 11. |
(5) |
Contingent Resources are defined in the COGE Handbook as those quantities of petroleum estimated, as of a given date, to be potentially recoverable from known accumulations using established technology or technology under development, but are not currently considered to be commercially recoverable due to one or more contingencies. Contingencies may include factors such as economic, legal, environmental, political and regulatory matters or a lack of markets. It is also appropriate to classify as contingent resources the estimated discovered recoverable quantities associated with a project in the early evaluation stage. Contingent Resources are further classified in accordance with the level of certainty associated with the estimates as described in footnote 11 and may be subclassified based on project maturity and/or characterized by their economic status. The Contingent Resources estimated in the GLJ Reserves and Resources Report are classified as "economic contingent resources", which are those contingent resources that are currently economically recoverable. All such resources are further sub-classified with a project status of "development pending", meaning that resolution of the final conditions for development are being actively pursued. The recovery estimates of the Company's contingent resources provided herein are estimates only and there is no guarantee that the estimated resources will be recovered. There is uncertainty that it will be commercially viable to produce any portion of the resources. Actual recovered resource may be greater than or less than the estimates provided herein. |
(6) |
Low Estimate: This is considered to be a conservative estimate of the quantity that will actually be recovered. It is likely that the actual remaining quantities recovered will exceed the low estimate. If probabilistic methods are used, there should be at least a 90 percent probability (P90) that the quantities actually recovered will equal or exceed the low estimate. |
(7) |
The net present value of future net revenue attributable to Alvopetro's reserves and resources are stated without provision for interest costs and general and administrative costs, but after providing for estimated royalties, production costs, development costs, other income, future capital expenditures, well abandonment and reclamation costs for only those wells assigned reserves and material dedicated gathering systems and facilities. The net present values of future net revenue attributable to Alvopetro's reserves and resources estimated by GLJ do not represent the fair market value of those reserves. Other assumptions and qualifications relating to costs, prices for future production and other matters are summarized herein. The recovery and reserve and resource estimates of the Company's reserves and resources provided herein are estimates only and there is no guarantee that the estimated reserves and resources will be recovered. Actual reserves and resources may be greater than or less than the estimates provided herein. |
(8) |
GLJ's January 1, 2023 escalated price forecast is used in the determination of future gas sales prices under Alvopetro's long-term gas sales agreement and for all forecasted oil sales and natural gas liquids sales. See https://www.gljpc.com/sites/default/files/pricing/Jan23.pdf for GLJ's price forecast. |
Alvopetro Energy Ltd.'s vision is to become a leading independent upstream and midstream operator in Brazil. Our strategy is to unlock the on-shore natural gas potential in the state of Bahia in Brazil, building off the development of our Caburé natural gas field and our strategic midstream infrastructure.
Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this news release.
All amounts contained in this news release are in United States dollars, except as otherwise noted.
Abbreviations:
1P = proved reserves
2P = proved plus probable reserves
3P = proved plus probable plus possible reserves
CAD = Canadian dollars
F&D = finding and development costs
FDC = future development costs;
Mbbl = thousands of barrels
Mboe = thousand barrels of oil equivalent
MMbtu = million British Thermal Units
MMcf = million cubic feet
MMcf/d = million cubic feet per day
MMboe = million barrels of oil equivalent
$000s = thousands of U.S. dollars
Oil and Natural Gas Reserves
The disclosure in this news release summarizes certain information contained in the GLJ Reserves and Resources Report but represents only a portion of the disclosure required under NI 51-101. Full disclosure with respect to the Company's reserves as at December 31, 2022 will be included in the Company's annual information form for the year ended December 31, 2022 which will be filed on SEDAR (www.sedar.com) on or before April 30, 2023. All net present values in this press release are based on estimates of future operating and capital costs and GLJ's forecast prices as of December 31, 2022. The reserves definitions used in this evaluation are the standards defined by COGEH reserve definitions and are consistent with NI 51-101 and used by GLJ. The net present values of future net revenue attributable to the Alvopetro's reserves estimated by GLJ do not represent the fair market value of those reserves. Other assumptions and qualifications relating to costs, prices for future production and other matters are summarized herein. The recovery and reserve estimates of the Company's reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual reserves may be greater than or less than the estimates provided herein. Possible reserves are those additional reserves that are less certain to be recovered than probable reserves. There is a 10% probability that the quantities actually recovered will equal or exceed the sum of proved plus probable plus possible reserves.
Contingent Resources
This news release discloses estimates of Alvopetro's contingent resources and the net present value associated with net revenues associated with the production of such contingent resources as included in the GLJ Reserves and Resources Report. There is no certainty that it will be commercially viable to produce any portion of such contingent resources and the estimated future net revenues do not necessarily represent the fair market value of such contingent resources. Estimates of contingent resources involve additional risks over estimates of reserves. Full disclosure with respect to the Company's contingent resources as at December 31, 2022 will be contained in the Company's annual information form for the year ended December 31, 2022 which will be filed on SEDAR (www.sedar.com) on or before April 30, 2023.
Prospective Resources
This news release discloses estimates of Alvopetro's prospective resources included in the GLJ Reserves and Resources Report. There is no certainty that any portion of the prospective resources will be discovered and even if discovered, there is no certainty that it will be commercially viable to produce any portion. Estimates of prospective resources involve additional risks over estimates of reserves. The accuracy of any resources estimate is a function of the quality and quantity of available data and of engineering interpretation and judgment. While resources presented herein are considered reasonable, the estimates should be accepted with the understanding that reservoir performance subsequent to the date of the estimate may justify revision, either upward or downward. Full disclosure with respect to the Company's prospective resources as at December 31, 2022 will be contained in the Company's annual information form for the year ended December 31, 2022 which will be filed on SEDAR (www.sedar.com) on or before April 30, 2023.
Boe Disclosure
The term barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet per barrel (6Mcf/bbl) of natural gas to barrels of oil equivalence is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. All boe conversions in this news release are derived from converting gas to oil in the ratio mix of six thousand cubic feet of gas to one barrel of oil.
Other Metrics
This press release contains metrics commonly used in the oil and natural gas industry, which have been prepared by management, including "F&D costs", "net asset value", "net asset value per share", "operating netback per boe", "production replacement ratio" and "recycle ratio". These terms do not have a standardized meaning and may not be comparable to similar measures presented by other companies, and therefore should not be used to make such comparisons.
"F&D costs" are reflected on a per barrel of oil equivalent and are calculated as the sum of capital expenditures in the current year plus the change in FDC for the period, divided by the change in reserves in the period, before current year production. The estimated 2022 F&D costs are computed as follows:
2022 capital expenditures(1) – $000s |
24,795 |
Change in FDC from 2021(2) – $000s |
10,540 |
Total - $000s |
35,335 |
Change in 2P reserves before 2022 production(3) – Mboe |
1,233 |
2022 estimated F&D costs (per boe) |
$28.66 |
(1) |
The estimated 2022 capital expenditures noted above are unaudited and subject to change upon completed of audited financial statements. Such changes could be material. See "Unaudited Financial Information" for further details. |
(2) |
Computed based on FDC costs from the 2P reserves in the December 31, 2022 GLJ Reserves and Resources Report less FDC costs from the December 31, 2021 GLJ Reserves and Resources Report. |
(3) |
Computed as the change in 2P reserves from December 31, 2021 to December 31, 2022 (which increased 300 Mboe, from 8,737 Mboe to 9,037 Mboe) plus 2022 total production of 933 Mboe. |
"Net asset value" is based on the before tax net present value of the Company's reserves as at December 31, 2022, discounted at 10% plus the Company's net working capital balance estimated as of December 31, 2022. Net working capital is a capital management measure. See "Non-GAAP and Other Financial Measures" below for further details. The estimated net working capital as of December 31, 2022 is unaudited and subject to change upon completion of audited financial statements for the year-ended December 31, 2022. Such changes could be material. See "Unaudited Financial Information" for further details.
"Net asset value per share" is based on the computation of net asset value divided by basic shares outstanding of 36,311,579 adjusted to Canadian dollars based on the foreign exchange rate on February 27, 2023.
"Operating netback per boe" is a non-GAAP financial measure and operating netback per boe is a non-GAAP financial ratio. See "Non-GAAP and Other Financial Measures" below for further details. Alvopetro's operating netback for the year ended December 31, 2022 is estimated at $59.43 per boe. This estimate is based on unaudited financial information and subject to change upon completion of audited financial statements for the year-ended December 31, 2022. Such changes could be material. See "Unaudited Financial Information" for further details.
"Production replacement ratio" is calculated as total reserve additions divided by current year production. Alvopetro's 2P production replacement ratio in 2022 is calculated as:
2P reserve additions (1) – Mboe |
1,233 |
2022 production – Mboe |
933 |
2022 2P production replacement ratio |
132 % |
(1) See computation in F&D costs above. |
"Recycle ratio" is calculated by dividing the estimated 2022 operating netback by estimated F&D costs per boe for the year. The Company's estimated 2022 recycle ratio is calculated as follows:
2022 estimated operating netback – $ per boe |
$59.43 |
2022 estimated F&D costs – $ per boe – see computation above |
$28.66 |
2P recycle ratio |
2.1 |
Management uses these oil and gas metrics for its own performance measurements and to provide shareholders with measures to compare our operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this press release, should not be relied upon for investment or other purposes.
This news release contains "forward-looking information" within the meaning of applicable securities laws. The use of any of the words "will", "expect", "intend" and other similar words or expressions are intended to identify forward-looking information. Forward-looking statements involve significant risks and uncertainties, should not be read as guarantees of future performance or results, and will not necessarily be accurate indications of whether or not such results will be achieved. A number of factors could cause actual results to vary significantly from the expectations discussed in the forward-looking statements. These forward-looking statements reflect current assumptions and expectations regarding future events. Accordingly, when relying on forward-looking statements to make decisions, Alvopetro cautions readers not to place undue reliance on these statements, as forward-looking statements involve significant risks and uncertainties. More particularly and without limitation, this news release contains forward-looking information concerning plans relating to the Company's operational activities, proposed development activities and the timing for such activities, capital spending levels and future capital costs, the expected natural gas price, gas sales and gas deliveries under Alvopetro's long-term gas sales agreement. The forward-looking statements are based on certain key expectations and assumptions made by Alvopetro, including but not limited to expectations and assumptions concerning the timing of regulatory licenses and approvals, equipment availability, the success of future drilling, completion, testing, recompletion and development activities, the performance of producing wells and reservoirs, well development and operating performance, expectations regarding Alvopetro's working interest and the outcome of any redeterminations, environmental regulation, including regulation relating to hydraulic fracturing and stimulation, the ability to monetize hydrocarbons discovered, the outlook for commodity markets and ability to access capital markets, foreign exchange rates, general economic and business conditions, the impact of the COVID-19 pandemic, weather and access to drilling locations, the availability and cost of labour and services, the regulatory and legal environment and other risks associated with oil and gas operations. The reader is cautioned that assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be incorrect. Actual results achieved during the forecast period will vary from the information provided herein as a result of numerous known and unknown risks and uncertainties and other factors. Although Alvopetro believes that the expectations and assumptions on which such forward-looking information is based are reasonable, undue reliance should not be placed on the forward-looking information because Alvopetro can give no assurance that it will prove to be correct. Readers are cautioned that the foregoing list of factors is not exhaustive. Additional information on factors that could affect the operations or financial results of Alvopetro are included in our annual information form which may be accessed on Alvopetro's SEDAR profile at www.sedar.com. The forward-looking information contained in this news release is made as of the date hereof and Alvopetro undertakes no obligation to update publicly or revise any forward-looking information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws.
Certain financial and operating information included in this news release for the year ended December 31, 2022 including, without limitation, 2022 capital expenditures and the impact on F&D costs, working capital, recycle ratio and operating netback, are based on estimated unaudited financial results for the year then ended, and are subject to the same limitations as discussed under Forward Looking Statements and Cautionary Language set out in this news release. These estimated amounts may change upon the completion of audited financial statements for the year ended December 31, 2022 and changes could be material.
This news release contains references to various non-GAAP financial measures, non-GAAP ratios, capital management measures and supplementary financial measures as such terms are defined in National Instrument 52-112 Non-GAAP and Other Financial Measures Disclosure. Such measures are not recognized measures under GAAP and do not have a standardized meaning prescribed by IFRS and might not be comparable to similar financial measures disclosed by other issuers. While these measures may be common in the oil and gas industry, the Company's use of these terms may not be comparable to similarly defined measures presented by other companies. The non-GAAP and other financial measures referred to in this news release should not be considered an alternative to, or more meaningful than measures prescribed by IFRS and they are not meant to enhance the Company's reported financial performance or position. These are complementary measures that are used by management in assessing the Company's financial performance, efficiency and liquidity and they may be used by investors or other users of this document for the same purpose. Below is a description of the non-GAAP financial measures, non-GAAP ratios, capital management measures and supplementary financial measures used in this news release. For more information with respect to financial measures which have not been defined by GAAP, including reconciliations to the closest comparable GAAP measure, see the "Non-GAAP Measures and Other Financial Measures" section of the Company's most recent MD&A which may be accessed through the SEDAR website at www.sedar.com .
Non-GAAP Financial Ratios
Operating netback per boe
Operating netback is calculated on a per unit basis, which is per barrel of oil equivalent ("boe"). It is a common non-GAAP measure used in the oil and gas industry and management believes this measurement assists in evaluating the operating performance of the Company. It is a measure of the economic quality of the Company's producing assets and is useful for evaluating variable costs as it provides a reliable measure regardless of fluctuations in production. Alvopetro calculated operating netback per boe as operating netback (a non-GAAP financial measure calculated as natural gas, oil and condensate revenues less royalties and production expenses) divided by total sales volumes (barrels of oil equivalent). More details on the method of calculation is provided in the "Operating Netback per boe" section of the Company's MD&A. The Company's MD&A may be accessed through the SEDAR website at www.sedar.com. Operating netback is a common metric used in the oil and gas industry used to demonstrate profitability from operations on a per unit basis (boe). The Company's operating netback per boe is estimated at $59.43 per boe for the year ended December 31, 2022. This amount is unaudited and subject to change as further discussed in the section "Unaudited Financial Information".
Capital Management Measures
Net Working Capital
Net working capital is computed as current assets less current liabilities. Net working capital is a measure of liquidity, is used to evaluate financial resources. The Company's net working capital as of December 31, 2022 is estimated at $14.7 million. This amount is unaudited and subject to change as further discussed in the section "Unaudited Financial Information".
SOURCE Alvopetro Energy Ltd.
Corey C. Ruttan, President, Chief Executive Officer and Director, or Alison Howard, Chief Financial Officer, Phone: 587.794.4224, Email: [email protected], www.alvopetro.com, TSX-V: ALV
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