2022 HIGHLIGHTS
- Peyto replaced 165%, 159% and 167% of annual production with new Proved Developed Producing, (“PDP”), Total Proved (“TP”), and Total Proved plus Probable (“P+P”) reserves using 64% of Funds from Operations1,2, (“FFO”) while growing annual production by 14% and reducing net debt1,2 by approximately
$210 million . - Peyto developed 374.5 BCFe3 (62.4 million barrels of oil equivalent, “MMboes”) of new PDP reserves at a Finding, Development and Acquisition (“FD&A”4) cost of
$1.41 /Mcfe ($8.48 /boe). Finding and Development costs exclusive of acquisitions were$1.35 /Mcfe for PDP reserves. Peyto’s 3 year average PDP FD&A cost is$1.15 /Mcfe. - FD&A costs, including the change in
Future Development Capital (“FDC”), for TP and P+P were$1.75 /Mcfe ($10.50 /boe) and$2.03 /Mcfe ($12.21 /boe), which reflects an increase in FDC, due to an increase in the number of future drilling locations and cost inflation, of$102 million and$244 million for the respective categories. For comparative purposes, FD&A costs before increases in FDC were$1.47 /Mcfe and$1.39 /Mcfe, respectively. Total Company reserve values (BT NPV5) for PDP, TP, and P+P reserves increased 59%, 43% and 32% on a debt adjusted per share basis to$27.18 /share,$49.50 /share, and$71.17 /share.Total Company reserve volumes for PDP, TP and P+P were up 8%, 4% and 3%, respectively, in absolute terms and increased 5%, 1% and 0%, respectively, on a per share basis.- Peyto’s extended reach horizontals (“ERH”) wells have shown a 186% improvement in reserves assigned and a 31% reduction in inflation adjusted development cost per mcfe.
- The Company’s average field netback1,5 was
$3.96 /Mcfe ($23.78 /boe), resulting in 2.8 times recycle ratio6 (3.9 times on an unhedged basis). One third of the wells drilled in 2022 have already paid out their initial capital investment. - The Reserve Life Index7 (“RLI”) for the PDP, TP and P+P reserves remained consistent year over year at 9, 15 and 24 years, respectively. Peyto’s PDP reserve life is one of the longest in the industry.
- At year end, P+P reserves of 929 MMboes (4.8TCF3 of gas, 66 MMbbls of pentanes and condensate, 27 MMbbls butane, 29 MMbbls propane and inclusive of 1,295 future locations) had been assigned to just 18.3% of Peyto’s total
Deep Basin petroleum and natural gas rights. - For the year ended
December 31, 2022 , Peyto invested$481 million of capital1,8 in organic activities to build approximately 38,100 boe/d at a cost of$12,600 boe/d9, which included$42 million in new plant construction but excluded$48 million in acquisitions which were purchased primarily for future opportunities and incremental plant processing capacity.
2023 CAPITAL BUDGET
- The Board of Directors of Peyto has approved a 2023 capital budget of $425–$475 million. Peyto, as always, will be nimble with capital plans and has specifically designed the program to have flexibility in the back half of the year when natural gas prices are forecasted to strengthen. Until that time, the Company plans to target the low end of capital guidance and will react to changes in commodity prices as they unfold. Peyto's plans for the
Whitehorse development, including associated gas plant and pipeline infrastructure, have been deferred as project economics have weakened with the decline in natural gas prices. Instead, capital previously earmarked forWhitehorse has been reallocated to other core areas to be focused on lower cost development drilling. Also included in the capital program is a 23 km large diameter pipeline to directly connect Peyto’sSwanson gas plant to the Cascade power plant currently under construction nearEdson, AB . This highly efficient 900 megawatt combined cycle power plant is expected to start operations in late 2023 and Peyto will supply 60,000 GJ/d (approximately 10% of current gas production) under a 15 year gas supply agreement. The 2023 capital program is projected to add between 35,000 and 40,000 boe/d of new production by year end, based on current onstream metrics of approximately$12,000 /boe/d. The capital program will more than offset the estimated 29% decline in base production allowing Peyto to target an exit rate between 110,000 to 115,000 boe/d. Similar to 2022, there may also be opportunities throughout the year for acquisitions that the Company chooses to pursue. - Peyto’s active hedging program has secured prices for approximately 55–60% of projected gas volumes for 2023, which provides revenue stability for the Company’s business plan. This level of price protection is one of the highest in industry. Peyto’s capital budget along with the current monthly dividend is forecasted to be funded with a portion of cashflow while the remainder will be used to reduce debt.
IMPROVED SUSTAINABILITY
- Low Production and Reserves Replacement10 Cost: The Company invested 64% of FFO in 2022 to replace over 165% of produced reserves in the year and grow PDP reserves by 8% implying only 39% of FFO would be required to replace produced reserves. Capital efficiency for 2022 was
$12,600 /boe/d for the organic drilling program excluding two separate acquisitions but inclusive of the construction of a new gas processing facility in Chambers. Capital efficiency was$13,600 /boe/d including the acquisitions which were purchased primarily for future resource upside and facility synergies in the Brazeau area. The cost to add new production increased over last year mainly due to increased service costs commensurate with higher natural gas prices. - Long Life, Low Decline Production: Peyto’s base production is forecasted by GLJ to fall to 75,000 boe/d in December of 2023, implying a 29% annual decline from 105,700 boe/d in
December 2022 . This annual production decline rate is lower than 2022 despite the 14% year-over-year production growth. Peyto’s PDP RLI is 9 years, based on Q4 2022 production rate of 104,950 boe/d, which is one of the longest PDP RLIs in the industry. - Low Risk Reserves: At year end, Peyto had 2003 gross (1,773 net) producing wells that are forecast to remain on production for decades to come. The lack of mobile water in the low permeability,
Deep Basin reservoirs combined with Peyto’s low-cost operations and efficient processing facilities results in very long producing lives for the existing proven producing wells that are exempt from the vulnerabilities of high-cost, third party midstream processing. - Minimal Liabilities: The forecast cost of Peyto’s future abandonment and reclamation liability (all wells, pipelines, well sites, & facilities) is
$69.4 million (NPV5), which represents 1% of the total$6.5 billion of forecast future value of the developed reserves11 (NPV5), illustrating Peyto’s disciplined, organic approach to finding and developing natural gas that has delivered one of the highest ratios of producing to non-producing wells in the industry. - Strong Environmental Performance: Peyto produces less than half of the average GHG emissions intensity of the natural gas production and processing industry in
Canada and is one of the lowest amongst its peers. Peyto has committed to reducing methane emissions intensity by 75% from 2016 levels and has active emissions reducing projects underway which include waste heat recovery, conversion of pneumatic chemical pumps to solar powered, installation of zero emissions pumps, and the removal of methane emitting equipment that is no longer required. The Company has begun construction of a gas pipeline that will directly supply the Cascade combined cycle, highly efficient, 900 megawatt power plant. This direct connection will result in transportation fuel savings of an estimated 25,000 tonnes of carbon dioxide equivalent per year. Peyto also uses less water per unit of production than many of its peers and continues to reduce the surface footprint needed to extract and develop reserves, annually. Please refer to Peyto’s 2022 ESG Report at: https://www.peyto.com/Files/Corporate%20Responsibility/ESG%20Committee/Peyto2022ESGReport.pdf
HISTORICAL PERSPECTIVE
- Over the past 24 years, Peyto has explored for and discovered 8.0 TCFe of
Alberta Deep Basin natural gas and associated liquids, of which 61% has now been developed11.
Peyto 24-year cumulative production (to | 2.461 TCFe | ||
Total Proved + Probable Developed reserves: | 2.433 TCFe | ||
Total Developed natural gas and liquids: | 4.894 TCFe | ||
Total Proved + Probable Undeveloped reserves: | 3.141 TCFe | ||
Total explored for and discovered: | 8.035 TCFe |
Each year the Company invests in the discovery of new reserves and the efficient and profitable development of existing reserves into high netback natural gas and NGL production for the purpose of generating the maximum possible return on capital for its shareholders.
- In those 24 years, a total of
$7.3 billion was invested in the Canadian economy in the acquisition and development of 4.9 TCFe of total developed natural gas and associated liquids at an average cost of$1.49 /Mcfe, while a weighted average field netback3 of$3.47 /Mcfe delivered$7.8 billion in FFO,$2.6 billion in dividends and distributions to shareholders, and resulted in a cumulative recycle ratio2 of 2.3 times. Royalty payments made toAlberta during this time have totaled over$1 billion . - Based on the
December 31, 2022 evaluation, the debt adjusted, Net Present Value of the Company’s remaining Total Proved plus Probable reserves (“P+P NPV”, 5% discount, less debt) was$71 /share, comprised of$35 /share of developed reserves and$36 /share of undeveloped reserves. This includes a provision for all abandonment liability for wells, well sites, pipelines, and facilities for which Peyto has ownership and responsibility.
2022 RESERVES REPORT AND ANALYSIS
The following table summarizes Peyto’s reserves and the discounted Net Present Value of future cash flows, before income tax, using the 3 Consultant Average (“3CA”) pricing forecast (GLJ, McDaniel, and Sproule), at
Before Tax Net Present Value ($millions) | ||||||||||||||||||||||
Discounted at | ||||||||||||||||||||||
Reserve Category | Gas (BCF) | Oil & NGL (mstb) | BCFe (6:1) | MMboe (6:1) | 0% | 5% | 8% | 10% | ||||||||||||||
Proved Developed Producing | 1,703 | 44,631 | 1,971 | 328 | 8,960 | 5,603 | 4,588 | 4,111 | ||||||||||||||
Proved Non-producing | 30 | 641 | 34 | 6 | 12 | 11 | 10 | 10 | ||||||||||||||
Proved Undeveloped | 1,329 | 34,757 | 1,537 | 256 | 6,911 | 3,861 | 2,879 | 2,409 | ||||||||||||||
Total Proved | 3,061 | 80,029 | 3,541 | 590 | 15,833 | 9,476 | 7,477 | 6,530 | ||||||||||||||
Probable | 1,774 | 43,125 | 2,033 | 339 | 8,960 | 3,760 | 2,525 | 2,004 | ||||||||||||||
Total Proved + Probable | 4,836 | 123,154 | 5,574 | 929 | 24,793 | 13,236 | 10,002 | 8,534 |
Note: Based on the GLJ report effective
ANALYSIS FOR PEYTO SHAREHOLDERS
One of the guiding principles at Peyto is “to tell you the business facts that we would want to know if our positions were reversed”. Therefore, each year Peyto provides an extensive analysis of the independent reserve evaluation that goes far beyond industry norms to answer the most important questions for shareholders:
- Base Reserves – How did the “base reserves” that were on production at the time of the last reserve report perform during the year, and how did any change in commodity price forecast affect their value?
- Value Creation – How much value did the 2022 capital investments create, both in current producing reserves and in undeveloped potential? Has the Peyto team earned the right to continue investing shareholders’ capital?
- Growth and Income – Are the projected cash flows capable of funding the growing number of undeveloped opportunities and a sustainable dividend stream to shareholders, without sacrificing Peyto’s financial flexibility or allowing for the timely repayment of any debt used?
- Risk Assessment – What are the risks associated with the assessment of Peyto’s reserves and the risk of recovering future cashflows from the forecast production streams?
1. Base Reserves
Peyto’s existing PDP reserves at the start of 2022 (the base reserves) were evaluated and adjusted for 2022 production as well as any technical or economic revisions resulting from the additional twelve months of production and commodity price data. As part of GLJ’s independent engineering analysis, all base 1,763 producing reserve entities (zones/wells) were evaluated. These base producing wells and zones represent a total gross Estimated Ultimate Recoverable (“EUR”) volume of 4.9 TCF (remaining PDP+PA reserves plus all cumulative production to date), which is within 1% from the prior year estimate. As a result, Peyto is pleased to report that its total base reserves continue to meet expectations, which provides confidence in the prediction of future recoveries.
The commodity price forecast used by GLJ in this year’s evaluation is higher than last year for both natural gas and natural gas liquids which has had the effect of increasing the Net Present Value of all reserve categories. For example, the debt adjusted NPV, discounted at 5%, of last year’s Proved Developed Producing reserves, increased
For 2023, GLJ is forecasting the total base production (PDP reserves) to decline to approximately 75,000 boe/d (395MMcf/d of gas and 9,560 bbl/d of NGLs) by
2012 | 2013 | 2014 | 2015 | 2016 | 2017 | 2018 | 2019 | 2020 | 2021 | 2022 | 2023F | |||||||||||||
Base Decline (%/yr)* | 35% | 34% | 38% | 40% | 40% | 37% | 35% | 29% | 23% | 27% | 30% | 29% | ||||||||||||
Capital Expenditures ($MM) |
*The base decline represents the aggregate annual decline of all wells on production at the end of the previous year.
2. Value Creation/Reconciliation
During 2022, Peyto invested a total of
Exploration, Development, and Acquisition Activity
Of the total capital invested in exploration and development activities (excluding acquisitions) in 2022, approximately 2% was spent acquiring lands and seismic, 21% on pipeline and facility projects, and the remaining 77% was spent drilling, completing, and connecting existing and new reserves. 79 of the gross wells drilled, or 83%, were previously identified as undeveloped reserves in last year’s reserve report (58 Proved, 21 Probable locations). The remaining 16 wells were locations developed in the year, on both existing and acquired lands, and were not recognized in last year’s report. Out of the 95 gross wells drilled in 2022, 90 wells were brought onstream during the year and 34 of those wells (36%) fully recovered their capital investment before the end of 2022.
During the first quarter of 2022, Peyto closed a strategic corporate acquisition in the Greater Brazeau area which added a 100% owned, operated, and underutilized 45 MMcf/d sweet natural gas plant, 850 boe/d of production from 20 net wells, and 73 net sections of land. The Company also closed a property acquisition in the Brazeau area in the third quarter which added 42 net sections of land and 650 boe/d from 12 net producing wells. Since that time, the Company has integrated the infrastructure within the existing Brazeau area complex to allow for efficient development of both assets and flexibility to maximize production from the area.
The undeveloped reserves at year end 2021 originally booked to the 79 drilled locations referred to above, totaled 331 BCFe (4.2 BCFe/well) of Proved plus Probable Undeveloped reserves for a forecast capital investment of
The following table illustrates the Company’s historical performance in converting predicted future undeveloped locations into producing wells and demonstrates that, other than the rapid inflation experienced in 2022, Peyto has typically converted more reserves at a lower cost than was forecast.
Reserve Year | Total Drills | Booked Locations Converted | Booked/Total | Forecast Outcome | Forecast Cost per Unit | Actual Outcome | Actual Cost per Unit | Actual/ Forecast Cost per Unit | |||||
gross wells | gross wells | BCFe | Capex* $MM | $/Mcfe | BCFe | Capex* $MM | $/Mcfe | ||||||
2010 | 48 | 30 | 63% | 84 | $1.46 | 102 | $1.35 | -8% | |||||
2011 | 70 | 51 | 73% | 152 | $1.41 | 151 | $1.38 | -2% | |||||
2012 | 86 | 60 | 70% | 189 | $1.56 | 196 | $1.42 | -9% | |||||
2013 | 99 | 69 | 70% | 206 | $1.61 | 218 | $1.42 | -12% | |||||
2014 | 123 | 90 | 73% | 278 | $1.50 | 288 | $1.45 | -3% | |||||
2015 | 140 | 103 | 74% | 307 | $1.49 | 348 | $1.11 | -26% | |||||
2016 | 128 | 82 | 64% | 254 | $1.17 | 254 | $0.97 | -17% | |||||
2017 | 142 | 97 | 68% | 298 | $0.99 | 321 | $0.95 | -4% | |||||
2018 | 70 | 37 | 53% | 104 | $1.10 | 120 | $0.98 | -11% | |||||
2019 | 61 | 39 | 64% | 129 | $0.86 | 123 | $0.88 | +2% | |||||
2020 | 64 | 52 | 81% | 172 | $0.92 | 165 | $0.82 | -11% | |||||
2021 | 95 | 61 | 64% | 221 | $0.87 | 227 | $0.84 | -3% | |||||
2022 | 95 | 79 | 83% | 331 | $268 | $0.81 | 333 | $320 | $0.96 | +19% | |||
Total | 1,221 | 850 | 70% | 2,725 | 3,274 | $1.20 | 2,846 | 3,164 | $1.11 | -8% |
*Capex represents only well related capital for drilling, completion, equipping and tie-in
This annual analysis of reserves that are converted from undeveloped to developed helps to validate the accuracy of the remaining future undeveloped reserves and the associated capital requirements. This accuracy helps Peyto predict future reserve recoveries and capital requirements and reduces the risk associated with valuing future undeveloped locations. While the Peyto team will do its utmost plans to continue to drive down costs in 2023, future development capital used in the reserves report for undeveloped locations reflects the most recent cost increases seen in 2022.
Value Reconciliation
In order to measure the success of all capital invested in 2022, it is necessary to quantify the total amount of value created during the year and compare that to the total amount of capital invested. Each year, Peyto runs last year’s reserve evaluation with this year’s price forecast to remove the change in value attributable to commodity prices. This approach isolates the value created by the Peyto team from the value created (or lost) by those changes outside of their control (ie. Commodity prices). Since the capital investments can be funded from a combination of cash flow, debt and equity, it is necessary to know the change in debt and the change in shares outstanding to see if the change in value is truly accretive to shareholders.
At year-end 2022, Peyto’s estimated net debt had decreased by 19% or
Based on this reconciliation of changes in BT NPV, the Peyto team was able to create
The historic NPV recycle ratios are presented in the following table.
2013 | 2014 | 2015 | 2016 | 2017 | 2018 | 2019 | 2020 | 2021 | 2022 | 10 yr Wt. Avg. | |
NPV0Recycle Ratio | |||||||||||
Proved Developed Producing | 1.5 | 1.5 | 2.3 | 2.9 | 2.3 | 4.6 | 1.8 | 3.5 | 5.2 | 3.6 | 2.7 |
Total Proved | 2.0 | 1.7 | 3.3 | 4.2 | 3.2 | 11.7 | 5.5 | 6.9 | 5.5 | 4.0 | 4.0 |
Total Proved + Probable | 4.0 | 2.6 | 5.0 | 7.3 | 4.0 | 15.1 | 9.2 | 6.5 | 11.5 | 3.8 | 5.8 |
*NPV0 (net present value) recycle ratio is calculated by dividing the undiscounted NPV of reserves added in the year by the total capital cost for the period (eg. 2022 Proved Developed Producing
3. Growth and Income
Over the past 19.5 years, Peyto has paid a total of
During 2022, the Company’s capital program was successful in replacing 165% of annual production with new PDP reserves, resulting in 8% growth, using only 64% of FFO. Fourth quarter production increased 7%, from 98,400 boe/d (522 MMcf/d gas, 11,300 bbl/d NGLs) to 104,950 boe/d (553 MMcf/d gas, 12,840 bbl/d NGLs). The change in both PDP reserves and fourth quarter production resulted in a slight increase of the Proved Developed Producing reserve life index (ratio of the two) from 8.5 years to 8.6 years.
For comparative purposes, the Total Proved and P+P RLI index was 15 and 24 years, respectively. Management believes that the most meaningful method to evaluate the current reserve life is by dividing the Proved Developed Producing reserves by the actual fourth quarter annualized production. This way production is being compared to producing reserves as opposed to producing plus non-producing reserves.
The following table highlights the Company’s historical RLI Index.
2007 | 2008 | 2009 | 2010 | 2011 | 2012 | 2013 | 2014 | 2015 | 2016 | 2017 | 2018 | 2019 | 2020 | 2021 | 2022 | |
Proved Developed Producing | 13 | 14 | 14 | 11 | 9 | 9 | 7 | 7 | 7 | 7 | 7 | 9 | 9 | 9 | 9 | 9 |
Total Proved | 16 | 17 | 21 | 17 | 16 | 15 | 12 | 11 | 11 | 11 | 11 | 16 | 19 | 18 | 16 | 15 |
Proved + Probable Additional | 21 | 23 | 29 | 25 | 22 | 22 | 19 | 18 | 17 | 18 | 18 | 25 | 29 | 27 | 25 | 24 |
Future Undeveloped Opportunities
As of
Peyto’s remaining undeveloped land base still holds significant future potential. GLJ has modelled a limited amount of development activity over the next eight years as shown in the following table of future development capital designed to ensure Peyto’s existing facilities remain full. This capital investment is projected to develop an additional 8.1% of Peyto 4,062 net sections of rights listed above.
Proved Reserves | Total Proved+Probable Reserves | |
Year | Undisc., ($Millions) | Undisc., ($Millions) |
2023 | 290 | 432 |
2024 | 401 | 435 |
2025 | 421 | 448 |
2026 | 382 | 450 |
2027 | 327 | 461 |
2028 | 240 | 419 |
2029 | 18 | 364 |
2030 | 2 | 459 |
Thereafter | 0 | 389 |
Total | 2,081 | 3,856 |
Every year Peyto finds and develops new drilling inventory that GLJ reviews to create a forecast of future development activity. Their forecast is by no means a complete assessment of Peyto’s current opportunities, nor is Peyto content to just sit back and harvest these current opportunities. Each year the results from the drilling activity spawn additional offsetting locations both on currently owned lands and lands Peyto does not yet own but attempts to acquire. In addition to the growth in inventory, Peyto has been evolving its horizontal well design to employ ERH laterals and increased stimulation intensity. This design allows more reservoir to be developed in each wellbore which has the effect of reducing the total number of wells required to develop a given resource. The result is a lower cost per unit of reserves and less off an environmental footprint. In the Wilrich specifically, Peyto has been able to extend lateral lengths consistently over 2,000 m, which has generated an 86% increase in per well recovery (4.1 Bcfe) over the previous well design (2.2 Bcfe). The increase in length and stimulation intensity costs have had the effect of lowering per unit development costs by 31% on an inflation adjusted basis from
As of
The undiscounted, forecast for Net Operating Income for the TP and P+P reserves over the future development capital schedule, as contained in the evaluator’s report, totals
The total estimated
4. Risk Assessment
Effectively 100% of Peyto’s natural gas and natural gas liquid reserves exist in low permeability (tight), sandstone reservoirs in the
In addition, these
Peyto’s high operating margins have meant that forecasts of net operating income are less affected by commodity price volatility than in most traditional reserve evaluations. As a result, the predicted economic life of Peyto’s producing wells is less sensitive to changes in commodity prices. These high operating margins are achieved through the Company’s high level of ownership and control of all levels of production operations, through a concentrated geographic asset base, and by striving to be the lowest cost producer in the industry.
Peyto attempts to further reduce the risk of predicted operating incomes with an active market diversification and hedging program that is designed, over time, to smooth out the volatility in both
Finally, Peyto is the operator of over 98% of its producing wells and has one of the highest ratios of producing to non-producing wells in the industry. Approximately 98% of Peyto’s asset base has been organically developed by Peyto and contains very few abandonment liabilities. As of
These cumulative factors listed above, which reduce the traditional risk of realizing future cashflows from Peyto’s reserves, is why, in Management’s opinion, Peyto’s reserves can be valued at lower discount rates than other, more conventional asset bases and why Management highlights Net Present Values (NPV) at 5% discount rates.
PERFORMANCE RATIOS
The following table highlights annual performance ratios for the last decade. These can be used for comparative purposes, but it is cautioned that on their own they do not measure investment success.
2022 | 2021 | 2020 | 2019 | 2018 | 2017 | 2016 | 2015 | 2014 | 2013 | ||||||||||||
Proved Developed Producing | |||||||||||||||||||||
FD&A ($/Mcfe) | $1.41 | ||||||||||||||||||||
RLI (yrs) | 8.6 | 9 | 9 | 9 | 9 | 7 | 7 | 7 | 7 | 7 | |||||||||||
Recycle Ratio | 2.8 | 2.8 | 1.5 | 1.4 | 2.3 | 2.1 | 1.8 | 2.0 | 1.9 | 1.6 | |||||||||||
Reserve Replacement | 165% | 188% | 127% | 75% | 98% | 171% | 153% | 193% | 183% | 190% | |||||||||||
Total Proved | |||||||||||||||||||||
FD&A ($/Mcfe) | $1.75 | ||||||||||||||||||||
RLI (yrs) | 15 | 16 | 18 | 19 | 16 | 11 | 11 | 11 | 11 | 12 | |||||||||||
Recycle Ratio | 2.3 | 2.4 | 8.0 | 1.7 | 2.2 | 2.0 | 2.6 | 4.5 | 1.8 | 1.6 | |||||||||||
Reserve Replacement | 159% | 194% | 132% | 137% | 294% | 225% | 183% | 188% | 254% | 230% | |||||||||||
$2,081 | |||||||||||||||||||||
Total Proved + Probable | |||||||||||||||||||||
FD&A ($/Mcfe) | $2.03 | ( | 1.02 | ||||||||||||||||||
RLI (yrs) | 24 | 25 | 27 | 29 | 25 | 18 | 18 | 17 | 18 | 19 | |||||||||||
Recycle Ratio | 1.9 | 2.5 | N/A | 1.7 | 2.6 | 1.9 | 4.2 | 6.1 | 2.1 | 2.0 | |||||||||||
Reserve Replacement | 167% | 308% | 167% | 140% | 342% | 279% | 283% | 287% | 328% | 450% | |||||||||||
$3,855 |
See Non-GAAP Financial Ratios in the Advisories section of this news release for details on the calculation of the above metrics.
RESERVES COMMITTEE
Peyto has a reserves committee, comprised of independent board members, that reviews the qualifications and appointment of the independent reserve evaluators. The committee also reviews the procedures for providing information to the evaluators. All booked reserves are based upon annual evaluations by the independent qualified reserve evaluators conducted in accordance with the COGE (Canadian Oil and Gas Evaluation) Handbook and National Instrument 51-101. The evaluations are conducted using all available geological and engineering data. The reserves committee has reviewed the reserves information and approved the reserve report.
MANAGEMENT CHANGES
Peyto is pleased to announce that
OUTLOOK
Despite the recent drop in price, the outlook for natural gas remains robust with the recognition that world demand continues to grow and the need for this critical energy supply will exist for the foreseeable future. The past warm winter in
GENERAL
A complete filing of the Statement of Reserves (form 51-101F1), Report on Reserves (form 51-101F2), and Report of Management and Directors on Oil and Gas Disclosure (form 51-101F3) will be available in the Annual Information Form to be filed by the end of
ADVISORIES
Unaudited Financial Information
Certain financial and operating information included in this news release including, without limitation, exploration and development expenditures, acquisitions, field netbacks, funds from operations, net debt, FD&A costs, Finding & Development costs excluding acquisitions, acquisition costs, and recycle ratio, are based on estimated unaudited financial results for the year ended
Information Regarding Disclosure on Oil and Gas Reserves
Some values set forth in the tables above may not add due to rounding. It should not be assumed that the estimates of future net revenues presented in the tables above represent 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 aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated future development costs generally will not reflect total finding and development costs related to reserves additions for that year.
Forward-Looking Information
This news release contains certain forward–looking information and statements within the meaning of applicable securities laws. The use of any of the words "expect", "anticipate", "continue", "estimate", "may", "will", "project", "should", "believe", "plans", "intends" and similar expressions are intended to identify forward-looking information or statements. In particular, but without limiting the foregoing, this news release contains forward-looking information and statements pertaining to the following: management's assessment of Peyto's future plans and operations, including the 2023 capital expenditure program, the volumes and estimated value of Peyto's reserves, the life of Peyto's reserves, production estimates, project economics including NPV, netback and recycle ratio, the ability to enhance value of reserves for shareholders and ensure the reserves generate the maximum possible return, the commencement of the Cascade Power Plant and the development and gas plant construction at
This news release contains information, including in respect of Peyto's 2023 capital program, which may constitute future oriented financial information or a financial outlook. Such information was approved by the Board of Directors of Peyto on
Barrels of Oil Equivalent
Boes may be misleading, particularly if used in isolation. A boe conversion ratio of 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. Given that the value ratio based on the current price of crude oil as compared to natural gas 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.
Non-GAAP and Other Financial Measures
Throughout this news release, Peyto employs certain measures to analyze financial performance, financial position, and cash flow. These non-GAAP and other financial measures do not have any standardized meaning prescribed under IFRS and therefore may not be comparable to similar measures presented by other entities. Such metrics have been included by Peyto to give readers additional measures to evaluate the Peyto's performance; however, such measures are not reliable indicators of the future performance of Peyto and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon.
Non-GAAP Financial Measures
Funds from Operations
"Funds from operations" is a non-GAAP measure which represents cash flows from operating activities before changes in non-cash operating working capital and provision for future performance-based compensation. Management considers funds from operations and per share calculations of funds from operations to be key measures as they demonstrate the Company’s ability to generate the cash necessary to pay dividends, repay debt and make capital investments. Management believes that by excluding the temporary impact of changes in non-cash operating working capital, funds from operations provides a useful measure of Peyto’s ability to generate cash that is not subject to short-term movements in operating working capital. The most directly comparable GAAP measure is cash flows from operating activities.
Capital Expenditures
Peyto uses the term capital expenditures as a measure of capital investment in exploration and production activity, as well as property acquisitions and divestitures, and such spending is compared to the Company's annual budgeted capital expenditures. The most directly comparable GAAP measure for total capital expenditures is cash flow used in investing activities.
Net Debt
"Net debt" is a non-GAAP financial measure that is the sum of long-term debt and working capital excluding the current financial derivative instruments and current portion of lease obligations. It is used by management to analyze the financial position and leverage of the Company. Net debt is reconciled to long-term debt which is the most directly comparable GAAP measure.
Non-GAAP Financial Ratios
Netback per MCFE
"Netback" is a non-GAAP measure that represents the profit margin associated with the production and sale of petroleum and natural gas. Peyto computes "field netback per Mcfe" as commodity sales from production, plus net third party sales, if any, plus other income, less royalties, operating, and transportation expense divided by production.
Finding, Development and Acquisition Cost
FD&A (finding, development and acquisition) costs are used as a measure of capital efficiency and are calculated by dividing the capital costs for the period, including the change in undiscounted FDC, by the change in the reserves, incorporating revisions and production, for the same period (eg. 2022 Total Proved ($529+$102)/(590.2-567.9+37.8) =
Reserve Life Index
The RLI is calculated by dividing the reserves (in boes) in each category by the annualized Q4 average production rate in boe/year (eg. 2022 Proved Developed Producing 328,424/(104.9x365) =8.6). Peyto believes that the most accurate way to evaluate the current reserve life is by dividing the proved developed producing reserves by the annualized actual fourth quarter average production. In Peyto’s opinion, for comparative purposes, the proved developed producing reserve life provides the best measure of sustainability.
Recycle Ratio
The Recycle Ratio is calculated by dividing the field netback per boe, by the FD&A costs for the period (eg. 2022 Proved Developed Producing
Reserve Replacement Ratio
The reserve replacement ratio is determined by dividing the yearly change in reserves before production by the actual annual production for the year (eg. 2022 Total Proved (590.2-567.9+37.8)/37.8 =159%).
Capital Efficiency
Capital efficiency is the cost to add new production in the year and is calculated as capital expenditures divided by total production added at year end (eg. 2022 Capital efficiency, before acquisitions ($481MM/38.1=
1 See "Unaudited Financial Information" in the Advisories section of this news release
2 Funds from operations and Net Debt are non-GAAP financial measures. See "non-GAAP and Other Financial Measures" in this news release
3 BCF and TCF refers to billions and trillions of cubic feet, respectively
4 FD&A is a non-GAAP financial ratio. See "non-GAAP and Other Financial Measures" in this news release
5 Field netback operations is a non-GAAP financial ratio. See "non-GAAP and Other Financial Measures" in this news release
6 Recycle ratio is a non-GAAP financial ratio. See "non-GAAP and Other Financial Measures" in this news release
7 RLI is a non-GAAP financial ratio. See "non-GAAP and Other Financial Measures" in this news release
8 Capital expenditures is a non-GAAP financial measure. See "non-GAAP and Other Financial Measures" in this news release
9 Capital efficiency is a non-GAAP financial ratio. See "non-GAAP and Other Financial Measures" in this news release
10 Reserve replacement is a non-GAAP financial ratio. See "non-GAAP and Other Financial Measures" in this news release
11 Developed Reserves is Total Proved + Probable Developed Reserves and includes Proved + Probable Developed Producing reserves and Proved + Probable Developed Non-Producing reserves.
Source:
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