Record 2019 Production and Adjusted Funds Flow
During the quarter and year ended
- Produced a record 57,010 Boe/d for the fourth quarter of 2019, or 16% greater than the respective quarter in 2018. Full year 2019 production was a record 50,803 Boe/d, or 26% greater than 2018 production. This represents annual production per weighted average share which was 6% greater than the prior year;
- Achieved
$70.1 million adjusted funds flow in the quarter, including over$17 million of free adjusted funds flow (net of capital expenditures); - Achieved record 2019 adjusted funds flow of
$266 million ($1.18 /share, basic); - Achieved adjusted funds flow netbacks of
$14.34 /Boe for 2019; - Executed a successful 2019 capital expenditure program of
$302 million , including$53 million in facilities expenditures and the drilling of 34 (34.0 net) wells in our condensate rich Wapiti Montney play. This level of capital is at the bottom of our original guidance range of$300 -$325 million ; - Reduced total annual operating expenses to
$9.61 /Boe; and - Achieved annual net G&A expenses of
$0.91 /Boe, continuing our long term trend of significant improvement with a reduction of 24% compared to 2018 G&A per Boe expenses.
Positive Reserves Revisions and Cost Reductions Drive Continued Improvements in Finding Costs and Reserves Value
NuVista is pleased to report the 2019 year end independent evaluation of our reserves by
- Achieved record Proven Developed Producing (“PDP”) F&D costs of
$10.26 /Boe which was driven by continued well cost reductions, positive technical revisions to existing reserves of 2.3% and continued strong well results; - Total Proven Plus Probable (“TP+PA”) F&D costs were
$8.94 /Boe, driven by positive technical revisions of 3.3% and robust undevelopedMontney location additions inPipestone ; - Generated PDP and TP+PA recycle ratios of 1.7x and 1.9x based on 2019 operating netback of
$17.06 /Boe; - Increased PDP and TP+PA reserves per basic share by 13% and 10% respectively to reach total reserve volumes of 95 MMBoe and 594 MMBoe, respectively;
- Increased our robust inventory of TP+PA undeveloped
Montney locations to 376. This reflects 10 years of booked inventory and includes an increase inPipestone locations by 14% to 144; - Achieved a reserves replacement ratio of 160% and 400% on a PDP and TP+PA basis, respectively, resulting in a TP+PA reserves life index (“RLI”) of over 27 years, and;
- Recognized the first reserve and resource additions in the emerging Charlie Lake Light Oil Play. Two PDNP and 22 undeveloped locations were booked. The undeveloped locations were booked on a gross TP+PA basis at 363 MBoe per well (51% oil) and
$4 .2MM cost to drill, complete, equip & tie-in. In addition, 225 gross locations have been booked in the Best Estimate Development Pending Contingent Resource category for a total risked volume of 45.9 MMBoe.
The detailed summary of our year end 2019 reserves disclosure is included further below, and will be included in our Annual Information Form which will be filed on or before
Excellence in Operations
Despite a late start to the winter drilling season due to adverse weather conditions, we are pleased to report that operations across our entire asset base have caught up to schedule as we progress through the first quarter of 2020. A total of 30 new
Production from the greater
At Pipestone North, we currently have two rigs drilling a 12-well pad, with completions scheduled to take place over the summer. The pad is expected to start up in the mid-fourth quarter of 2020 commensurate with the startup of the new
Water sourcing and disposal activities have proceeded exceptionally well in the area. We have successfully completed construction of our water storage complex and are in the process of connecting both a non-potable water source well and a produced water deep disposal well. These projects reduce completion capital and operating costs while enhancing our ESG performance through the reduction of freshwater use, the elimination of truck traffic dust and noise on local roads, and the commensurate reduction in GHG emissions.
As previously reported, NuVista experienced challenging third-party
At Pipestone South, our initial 11 wells have now reached IP90 (an 8-well pad and a 3-well pad). Our third pad (6 wells) has been drilled and completed and has recently come on production in the first quarter of 2020. The total cost to drill, complete, equip, and tie-in our third pad averaged
South IP90 Table | Average Hz. Length | Condensate | Condensate Gas Ratio | Total | | ||
Meters | MMcf/d | Bbls/d | Bbls/MMcf | Boe/d | $MM | ||
11-well Average | 2,070 | 6,000 | 443 | 72 | 1,230 | $ | 6.8 |
Rich type curve | 3,000 | 7,000 | 515 | 74 | 1,654 | $ | 8.4 |
Wapiti
Production from the Wapiti area has been steady through the fourth quarter of 2019 and into early 2020 at approximately 35,000 Boe/d including 32% condensate. Our intention is to keep volumes in the Wapiti area relatively flat by offsetting natural declines with the startup of several newly drilled pads in the first and second quarters of 2020. A new 2-well pad at Bilbo has recently come online and it is expected to be followed by 4 additional wells in the third quarter. 4 wells at Elmworth and 3 wells at
Notable performance milestones have been reached in both Bilbo and Elmworth. Five wells reached IP365 at Bilbo, producing an average of 295 Bbls/d of condensate. This is within 4% of the Bilbo historic average condensate rate, but these wells were executed with drilling and completion (D&C) cost per horizontal meter 16% lower than our historic average. At Elmworth, six wells reached their IP180 milestone. The D&C costs for these wells were 34% below our historic average for the area, while condensate rates averaged 324 Bbls/d which is 33% above the historic Elmworth average.
Keeping The Balance Sheet Strong
Continued growth in our
Significant Commodity Price Diversification and Risk Management
NuVista continues to benefit from the discipline of our strong rolling hedge program during this period of volatile commodity prices. World oil prices had been strengthening based on reduced Permian basin production growth rates,
ESG Progress Continues
We are proud to have demonstrated our commitment to transparency and ethical practices in our inaugural Environmental, Social, and Governance (“ESG”) report earlier in 2019. This report, available for viewing on NuVista’s website, provides a comprehensive look at NuVista’s ESG practices while highlighting the proactivity and excellent execution our teams have always demonstrated in advancement of our ESG performance. Key highlights of the report include our high safety and environmental performance, our long term progress in reducing GHG intensity, and our strong governance and community focus. Approximately 70% of our current production is comprised of natural gas which has the lowest carbon footprint of any hydrocarbon, leading to our GHG performance being well below the North American benchmark. We continue to execute projects to enhance our ESG progress, and we look forward to providing updated ESG reporting in the future.
Board and Committee Changes
In pursuit of board renewal and new exposures, we would like to announce some key board and committee changes. Mr.
In addition, we are pleased to announce recent changes to our Board committees in light of our increased focus on ESG initiatives. We have established an ESG Committee, the members of which will be: Mr.
2020 Guidance Re-Affirmed, But Monitoring Commodity Price Pressure
NuVista is pleased to provide an update on our 2020 plans in light of the extreme volatility in the current commodity markets. The primary governor on our annual plan will remain as always to maintain the balance between capital spending and adjusted funds flow in order to protect the balance sheet first. This then allows us to grow production volumes at a comfortable pace commensurate with the flexibility in our future volume commitments.
Our 2020 guidance range is for production of 57,000 Boe/d with capital spending of
As anticipated, we expect capital spending of
As previously communicated, we expect the third party downtime issues which are affecting production in the first quarter, to gradually improve towards the spring. In addition, we have been required to temporarily shut in certain producing wells for fracture treatments on adjacent newly drilled wells in
NuVista has top quality assets and a management team focused upon relentless improvement. We are excited to continue pursuing our
Corporate Highlights | ||||||||||||||||
Three months ended | Year ended | |||||||||||||||
($ thousands, except per share and $/Boe) | 2019 | 2018 | % Change | 2019 | 2018 | % Change | ||||||||||
FINANCIAL | ||||||||||||||||
Petroleum and natural gas revenues | 156,479 | 143,006 | 9 | 561,095 | 555,849 | 1 | ||||||||||
Adjusted funds flow (1) (2) | 70,080 | 63,635 | 10 | 265,851 | 264,448 | 1 | ||||||||||
Per share - basic | 0.31 | 0.28 | 11 | 1.18 | 1.39 | (15 | ) | |||||||||
Per share - diluted | 0.31 | 0.28 | 11 | 1.18 | 1.38 | (14 | ) | |||||||||
Net earnings (loss) | (29,557 | ) | 104,086 | (128 | ) | (63,833 | ) | 136,245 | (147 | ) | ||||||
Per share - basic | (0.13 | ) | 0.46 | (128 | ) | (0.28 | ) | 0.71 | (139 | ) | ||||||
Per share - diluted | (0.13 | ) | 0.46 | (128 | ) | (0.28 | ) | 0.71 | (139 | ) | ||||||
Total assets | 2,331,361 | 2,180,874 | 7 | |||||||||||||
Assets acquired | — | 1,679 | — | — | 619,444 | — | ||||||||||
Capital expenditures (2) | 52,814 | 77,433 | (32 | ) | 301,822 | 340,792 | (11 | ) | ||||||||
Net debt (1) (2) | 561,975 | 511,408 | 10 | |||||||||||||
End of period basic common shares outstanding | 225,592 | 225,306 | — | |||||||||||||
OPERATING | ||||||||||||||||
Daily Production | ||||||||||||||||
Natural gas (MMcf/d) | 204.3 | 174.3 | 17 | 182.3 | 144.7 | 26 | ||||||||||
Condensate & oil (Bbls/d) | 17,195 | 14,766 | 16 | 15,170 | 12,674 | 20 | ||||||||||
NGLs (Bbls/d) (3) | 5,769 | 5,246 | 10 | 5,246 | 3,554 | 48 | ||||||||||
Total (Boe/d) | 57,010 | 49,060 | 16 | 50,803 | 40,353 | 26 | ||||||||||
Condensate, oil & NGLs weighting | 40 | % | 41 | % | 40 | % | 40 | % | ||||||||
Condensate & oil weighting | 30 | % | 30 | % | 30 | % | 31 | % | ||||||||
Average selling prices (4) (5) | ||||||||||||||||
Natural gas ($/Mcf) | 2.74 | 3.69 | (26 | ) | 2.78 | 3.51 | (21 | ) | ||||||||
Condensate & oil ($/Bbl) | 62.51 | 51.60 | 21 | 64.06 | 70.92 | (10 | ) | |||||||||
NGLs ($/Bbl) | 11.51 | 28.53 | (60 | ) | 11.06 | 32.83 | (66 | ) | ||||||||
Netbacks ($/Boe) | ||||||||||||||||
Petroleum and natural gas revenues | 29.83 | 31.69 | (6 | ) | 30.26 | 37.74 | (20 | ) | ||||||||
Realized gain (loss) on financial derivatives | 0.75 | (2.37 | ) | — | 0.94 | (2.60 | ) | — | ||||||||
Royalties | (1.82 | ) | (1.07 | ) | 70 | (1.49 | ) | (1.10 | ) | 35 | ||||||
Transportation expenses | (2.83 | ) | (2.93 | ) | (3 | ) | (3.04 | ) | (3.06 | ) | (1 | ) | ||||
Operating expenses | (9.63 | ) | (9.06 | ) | 6 | (9.61 | ) | (9.75 | ) | (1 | ) | |||||
Operating netback (2) | 16.30 | 16.26 | — | 17.06 | 21.23 | (20 | ) | |||||||||
Corporate netback (2) | 13.37 | 14.11 | (5 | ) | 14.34 | 17.96 | (20 | ) | ||||||||
SHARE TRADING STATISTICS | ||||||||||||||||
High | 3.24 | 7.75 | (58 | ) | 5.19 | 9.89 | (48 | ) | ||||||||
Low | 1.86 | 3.38 | (45 | ) | 1.39 | 3.38 | (59 | ) | ||||||||
Close | 3.19 | 4.08 | (22 | ) | 3.19 | 4.08 | (22 | ) | ||||||||
Average daily volume ('000s) | 769,852 | 1,153,619 | (33 | ) | 1,212,077 | 719,389 | 68 |
- Refer to Note 18 "Capital management" in NuVista's financial statements and to the sections entitled "Adjusted funds flow" and "Liquidity and capital resources" contained in NuVista's MD&A.
- Non-GAAP measure that does not have any standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other companies where similar terminology is used. Reference should be made to the section entitled "Non-GAAP measurements".
- Natural gas liquids ("NGLs") include butane, propane and ethane.
- Product prices exclude realized gains/losses on financial derivatives.
- The average condensate and NGLs selling price is net of pipeline tariffs and fractionation fees.
Detailed Summary of Corporate Reserves Data
The following table provides summary reserve information based upon the GLJ Report using the published GLJ
Natural Gas(2) | Natural Gas Liquids | Oil(3) | Total | |
Reserves category(1) | Company Gross | Company Gross | Company Gross | Company Gross |
Interest | Interest | Interest | Interest | |
(MMcf) | (MBbls) | (MBbls) | (MBoe) | |
Proved | ||||
Developed producing | 364,079 | 33,511 | 669 | 94,860 |
Developed non‑producing | 59,375 | 5,025 | 279 | 15,200 |
Undeveloped | 969,971 | 79,644 | 2,072 | 243,379 |
Total proved | 1,393,425 | 118,180 | 3,021 | 353,438 |
Probable | 960,109 | 77,227 | 3,066 | 240,311 |
Total proved plus probable | 2,353,534 | 195,407 | 6,087 | 593,749 |
NOTES:
(1) Numbers may not add due to rounding.
(2) Includes conventional natural gas and shale gas and coal bed methane.
(3) Includes light and medium crude oil.
The following table is a summary reconciliation of the 2019 year end working interest reserves with the working interest reserves reported in the 2018 year end reserves report:
Natural Gas(1)(3) (MMcf) | Liquids(1) (MBbls) | Oil(1)(4) (MBbls) | Total Oil Equivalent(1) (MBoe) | |||||
Total proved | ||||||||
Balance, | 1,274,334 | 110,365 | 1,826 | 324,580 | ||||
Exploration and development(2) | 120,639 | 10,395 | 1,612 | 32,113 | ||||
Technical revisions | 65,117 | 4,881 | (260 | ) | 15,474 | |||
Acquisitions | - | - | - | - | ||||
Dispositions | - | - | - | - | ||||
Economic Factors | (118 | ) | (166 | ) | 1 | (185 | ) | |
Production | (66,548 | ) | (7,295 | ) | (157 | ) | (18,543 | ) |
Balance, | 1,393,425 | 118,180 | 3,021 | 353,438 | ||||
Total proved plus probable Total proved plus probable | ||||||||
Balance, | 2,130,548 | 180,213 | 2,425 | 537,728 | ||||
Exploration and development(2) | 214,268 | 16,771 | 4,230 | 56,712 | ||||
Technical revisions | 75,355 | 5,734 | (411 | ) | 17,882 | |||
Acquisitions | - | - | - | - | ||||
Dispositions | - | - | - | - | ||||
Economic Factors | (90 | ) | (15 | ) | - | (30 | ) | |
Production | (66,548 | ) | (7,295 | ) | (157 | ) | (18,543 | ) |
Balance, | 2,353,534 | 195,407 | 6,087 | 593,749 |
NOTES:
(1) Numbers may not add due to rounding.
(2) Reserve additions for drilling extensions, infill drilling and improved recovery.
(3) Includes conventional natural gas, shale gas and coal bed methane.
(4) Includes light, medium crude oil.
The following table summarizes the future development capital included in the GLJ Report:
($ thousands, undiscounted) | Proved | Proved plus probable |
2020 | 156,311 | 184,740 |
2021 | 479,741 | 516,206 |
2022 | 497,545 | 560,655 |
2023 | 494,141 | 541,459 |
2024 | 394,596 | 429,165 |
Remaining | - | 875,988 |
Total (Undiscounted) | 2,022,335 | 3,108,211 |
NOTE:
(1) Numbers may not add due to rounding.
The following table outlines NuVista's corporate finding, development and acquisition costs in more detail:
3 Year-Average (1) | 2019 (1) | 2018 (1) | ||||||||||
Proved plus | Proved plus | Proved plus | ||||||||||
Proved | probable | Proved | probable | Proved | probable | |||||||
Finding and development costs ($/Boe) | $ | 9.05 | $ | 7.45 | $ | 10.30 | $ | 8.94 | $ | 7.80 | $ | 6.43 |
Finding, development and acquisition costs ($/Boe) | $ | 10.24 | $ | 8.04 | $ | 10.30 | $ | 8.94 | $ | 10.33 | $ | 8.22 |
NOTE:
(1) F&D costs and FD&A are used as a measure of capital efficiency. The calculation for F&D costs includes all exploration and development capital for that period as outlined in the Company’s year-end financial statements plus the change in future development capital for that period. This total capital including the change in the future development capital is then divided by the change in reserves for that period including revisions for that same period. The aggregate of the exploration and development costs incurred in the most recent financial year and the change during the year in estimated future development costs generally will not reflect total finding and development costs related to reserve additions for the year. FD&A costs are calculated in the same manner except in addition to exploration and development capital and the change in future development capital, acquisition capital is also included in the calculation.
Summary of Corporate Net Present Value Data
The estimated net present values of future net revenue before income taxes associated with NuVista’s reserves effective
The estimated future net revenue contained in the following table does not necessarily represent the fair market value of the reserves. There is no assurance that the forecast price and cost assumptions contained in the GLJ Report will be attained and variations could be material. The recovery and reserve estimates described herein are estimates only. Actual reserves may be greater or less than those calculated.
Before Income Taxes | ||||||||||
Discount Factor (%/year) | ||||||||||
Reserves category (1) ($ thousands) | 0 | % | 5 | % | 10 | % | 15 | % | 20 | % |
Proved | ||||||||||
Developed producing | 1,292,957 | 1,074,708 | 894,066 | 766,667 | 675,143 | |||||
Developed non‑producing | 235,812 | 171,698 | 134,355 | 110,644 | 94,428 | |||||
Undeveloped | 3,024,261 | 1,743,436 | 1,081,329 | 705,077 | 473,909 | |||||
Total proved | 4,553,030 | 2,989,842 | 2,109,750 | 1,582,388 | 1,243,480 | |||||
Probable | 3,995,971 | 1,895,163 | 1,070,610 | 684,758 | 477,200 | |||||
Total proved plus probable | 8,549,000 | 4,885,004 | 3,180,360 | 2,267,147 | 1,720,679 |
(1) Numbers may not add due to rounding.
The following table is a summary of pricing and inflation rate assumptions based on published GLJ forecast prices and costs as at
Year | AECO Gas ($Cdn/ MMBtu) | NYMEX Gas ($US/ MMBtu) | Midwest Gas at ($US/ MMBtu) | C5+ ($Cdn/Bbl) | Propane ($Cdn/Bbl) | Butane ($Cdn/Bbl) | WTI ($US/Bbl) | Par Price 40 API ($Cdn/Bbl) | Exchange Rate(2) ($US/$Cdn) | ||||||
Forecast | |||||||||||||||
2020 | 2.08 | 2.42 | 2.32 | 77.80 | 28.68 | 48.76 | 61.00 | 71.71 | 0.76 | ||||||
2021 | 2.35 | 2.75 | 2.65 | 79.22 | 31.09 | 51.82 | 63.00 | 74.03 | 0.77 | ||||||
2022 | 2.55 | 2.90 | 2.80 | 83.33 | 34.62 | 54.62 | 66.00 | 76.92 | 0.78 | ||||||
2023 | 2.65 | 3.00 | 2.90 | 86.54 | 36.06 | 56.89 | 68.00 | 80.13 | 0.78 | ||||||
2024 | 2.75 | 3.10 | 3.00 | 89.10 | 37.21 | 58.71 | 70.00 | 82.69 | 0.78 | ||||||
2025 | 2.85 | 3.20 | 3.10 | 91.67 | 38.37 | 60.53 | 72.00 | 85.26 | 0.78 | ||||||
2026 | 2.91 | 3.27 | 3.17 | 94.23 | 39.52 | 62.35 | 74.00 | 87.82 | 0.78 | ||||||
2027 | 2.97 | 3.33 | 3.23 | 96.55 | 40.56 | 64.00 | 75.81 | 90.14 | 0.78 | ||||||
2028 | 3.03 | 3.40 | 3.30 | 98.50 | 41.44 | 65.38 | 77.33 | 92.09 | 0.78 | ||||||
2029 | 3.09 | 3.47 | 3.37 | 100.49 | 42.33 | 66.79 | 78.88 | 94.08 | 0.78 | ||||||
2030+ | +2.0%/yr | +2.0%/yr | +2.0%/yr | +2.0%/yr | +2.0%/yr | +2.0%/yr | +2.0%/yr | +2.0%/yr | 0.78 | ||||||
NOTES:
(1) Costs are inflated at 2% per annum.
(2) Exchange rate used to generate the benchmark reference prices in this table.
(3) NuVista’s future realized gas prices are forecasted based on a combination of various benchmark prices in addition to the AECO benchmark in order to reflect the favorable price diversification to other markets which NuVista has undertaken. Pricing at these markets has been accounted for in the GLJ Report. Additional information on NuVista’s gas marketing diversification will be available in our corporate presentation.
Charlie Lake Resource Evaluation
Risked and Unrisked ECR Development Pending (1)(2)(3)(4)(5) | Chance of Development | Best Estimate Unrisked | Best Estimate Risked | |
81 | % | 89.4 | 72.4 | |
Natural Gas Liquids (MMBbls) | 81 | % | 12.1 | 9.8 |
Oil (MMBbls) | 81 | % | 29.7 | 24.1 |
Oil Equivalent (MMBoe) | 81 | % | 56.7 | 45.9 |
Before tax NPV ($ millions) | ||||
Undiscounted | 1,210 | 980 | ||
Discounted at 10% | 428 | 347 |
- All volumes listed in the table are company gross and sales volumes.
- Estimated contingent resource as per GLJ Independent Resource Evaluation as of
December 31, 2019 and based on GLJ forecast pricing and foreign exchange rates atJanuary 1, 2020 . - Risk in the above table is the chance of development. In quantifying the chance of development, factors that were assessed quantitatively to be less than one in the risking calculation included the economic status, the development plan and the development time frame.
- Contingent resources are discovered resources by definition.
- There is uncertainty that it will be commercially viable to produce any portion of the resources.
Advisories Regarding Oil And Gas Information
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. As the value ratio between natural gas and crude oil based on the current prices of natural gas and crude oil is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
This news release contains a number of oil and gas metrics prepared by management, including F&D costs, FD&A costs, recycle ratio, reserves replacement ratio and RLI, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies. Such metrics have been included herein to provide readers with additional measures to evaluate NuVista's performance on a comparable basis with prior periods; however, such measures are not reliable indicators of the future performance of NuVista and future performance may not compare to the performance in previous periods. Details of how F&D and FD&A costs have been calculated are included in the body of this news release. Recycle ratio has been calculated by dividing operationing netback (refer to Non-GAAP Measurements) by F&D costs and FD&A costs per Boe for the applicable period.
Any references in this press release to initial production rates are useful in confirming the presence of hydrocarbons, however, such rates are not determinative of the rates at which such wells will continue production and decline thereafter. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production for NuVista. NuVista has presented the
Such type curves are useful in understanding management's assumptions of well performance in making investment decisions in relation to development drilling in the
For the
NuVista is still in the early days of piloting extended reach horizontals and high intensity facture techniques and in the early stages of development in respect of the
Resources Disclosure
Resources estimates presented herein have been prepared by GLJ, NuVista’s independent qualified reserves evaluators, in accordance with the Canadian Oil and Gas Evaluation Handbook (the "COGE Handbook"), have an effective date of
Resources volumes attributed to NuVista’s CLLK properties are estimates only. There is no assurance that the estimated resources can or will be recovered. Actual resources may be greater or less than those estimated, and the difference may be material.
The determination of oil and gas resources involves estimating subsurface accumulations of oil, natural gas liquids and natural gas that cannot be exactly measured. The preparation of estimates is subject to an inherent degree of associated risk and uncertainty, including factors that are beyond NuVista’s control. The estimation and classification of resources is a complex process involving the application of professional judgment combined with geological and engineering knowledge to assess whether specific classification criteria have been satisfied. It requires significant judgments based on available geological, geophysical, engineering, and economic data as well as forecasts of commodity prices and anticipated costs. As circumstances change and additional data becomes available, whether through the results of drilling, testing and production or from economic factors such as changes in product prices or development and production costs, reserves estimates also change. Revisions may be positive or negative.
Certain contingencies currently prevent the classification of NuVista’s contingent resources as reserves. The 45.9 MMboe Best Estimate Contingent Resources disclosed in this news release include NuVista’s Risked Best Estimate Development Pending Contingent Resources in NuVista's
All of NuVista’s contingent resources disclosed in this news release have been sub-classified as “Development Pending”, which applies in circumstances where resolution of the final conditions for development is being actively pursued and indicates a relatively high chance of development versus the other sub-classifications.
All of NuVista’s contingent resources have been risked using an 81% chance of development. In quantifying the chance of development, the factors that were assessed quantitatively to be less than one in the development risk calculation included the economic, the development plan, and the development time frame. The chance of development multiplied by the unrisked resource volume estimate yields the risked resource volume estimate. As many of these factors have a wide range of uncertainty and are difficult to quantify, the chance of development is an uncertain value that should be used with caution.
Continuous development through multi-year exploration and development programs and significant levels of future capital expenditures are required in order for additional resources to be recovered in the future. The principal risks that would inhibit the recovery of additional reserves relate to the potential for variations in the quality of the CLLK formation where minimal well data currently exists, access to the capital required to develop the resources, low commodity prices that would curtail the economics of development, future performance of wells, regulatory approvals, access to required services at an appropriate cost, and the effectiveness of well fracturing technology and applications. For contingent resources to be converted to reserves, NuVista must ascertain commercial production rates, then develop firm plans, including with respect to timing, infrastructure and the commitment of capital. Confirmation of commercial productivity is generally required before NuVista can prepare firm development plans and commit required capital for the development of the contingent resources. Additional contingencies relate to infrastructure build-out requirements to develop the resources in a relatively quick time frame. As continued delineation occurs, some resources currently classified as contingent resources are expected to be re-classified to reserves.
The estimated cost reflected in GLJ evaluation of NuVista’s contingent resources to bring on commercial production from the Risked Best Estimate Development Pending Contingent Resources is approximately
The estimates of contingent resources provided herein are estimates only and there is no guarantee that the estimated contingent resources will be recovered. Actual contingent resources may be greater or less than the estimates provided in this news release, and the differences may be material. The estimates of contingent for individual properties may not reflect the same confidence level as estimates of contingent for all properties, due to the effects of aggregation. There is no assurance that the forecast price and cost assumptions applied by GLJ in evaluating NuVista’s contingent resources will be attained and variances could be material. There is uncertainty that it will be commercially viable to produce any portion of the contingent resources described herein, or that NuVista will produce any portion of the volumes currently classified as contingent resources.
Advisory regarding forward-looking information and statements
This news release contains forward-looking statements and forward-looking information (collectively, “forward-looking statements”) within the meaning of applicable securities laws. The use of any of the words “will”, “expects”, “believe”, “plans”, “potential” and similar expressions are intended to identify forward-looking statements. More particularly and without limitation, this news release contains forward looking statements, including management's assessment of: NuVista’s future focus, strategy, plans, opportunities and operations; production decline rates;
By their nature, forward-looking statements are based upon certain assumptions and are subject to numerous risks and uncertainties, some of which are beyond NuVista’s control, including the impact of general economic conditions, industry conditions, current and future commodity prices, currency and interest rates, anticipated production rates, borrowing, operating and other costs and adjusted funds flow, the timing, allocation and amount of capital expenditures and the results therefrom, anticipated reserves and the imprecision of reserve estimates, the performance of existing wells, the success obtained in drilling new wells, the sufficiency of budgeted capital expenditures in carrying out planned activities, access to infrastructure and markets, competition from other industry participants, availability of qualified personnel or services and drilling and related equipment, stock market volatility, effects of regulation by governmental agencies including changes in environmental regulations, tax laws, production curtailment and royalties; the ability to access sufficient capital from internal sources and bank and equity markets; and including, without limitation, those risks considered under “Risk Factors” in our Annual Information Form. Readers are cautioned that the assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be imprecise and, as such, undue reliance should not be placed on forward-looking statements. NuVista’s actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements, or if any of them do so, what benefits NuVista will derive therefrom. NuVista has included the forward-looking statements in this news release in order to provide readers with a more complete perspective on NuVista’s future operations and such information may not be appropriate for other purposes. NuVista disclaims any intention or obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except as required by law.
Non-GAAP measurements
Within the news release, references are made to terms commonly used in the oil and natural gas industry. Management uses "adjusted funds flow", "adjusted funds flow per share", “adjusted funds flow netback”, "operating netback", "corporate netback", "capital expenditures", "net debt” and “net debt to 12 month trailing adjusted funds flow” to analyze performance and leverage. These terms do not have any standardized meaning prescribed by IFRS and therefore may not be comparable to similar measures presented by other companies where similar terminology is used. For further information refer to the section "Non-GAAP measurements" contained in NuVista's MD&A for the year ended
Basis of presentation
Unless otherwise noted, the financial data presented has been prepared in accordance with Canadian generally accepted accounting principles (“GAAP”) also known as International Financial Reporting Standards (“IFRS”). The reporting and measurement currency is the Canadian dollar. Natural gas is converted to a barrel of oil equivalent (“Boe”) using six thousand cubic feet of gas to one barrel of oil. In certain circumstances natural gas liquid volumes have been converted to a thousand cubic feet equivalent (“Mcfe”) on the basis of one barrel of natural gas liquids to six thousand cubic feet of gas. National Instrument 51-101 - "Standards of Disclosure for Oil and Gas Activities" includes condensate within the product type of natural gas liquids. NuVista has disclosed condensate values separate from natural gas liquids herein as NuVista believes it provides a more accurate description of NuVista's operations and results therefrom.
Reserves advisories
The reserves estimates prepared herein have been evaluated by an independent qualified reserves evaluator in accordance with National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities and the Canadian Oil and Gas Evaluation Handbook ("COGE Handbook") and are effective as of
The recovery and reserve estimates contained herein are estimates only and there is no guarantee that the estimated reserves will be recovered.
This press release discloses drilling inventory in three categories: (i) proved locations; (ii) probable locations, and; (iii) best estimate contingent drilling locations. Proved and probable locations are derived from a report prepared by GLJ, NuVista’s independent qualified reserves evaluator, evaluating NuVista’s reserves as of
FOR FURTHER INFORMATION CONTACT:
President and CEO
(403) 538-8501
VP, Finance and CFO
(403) 538-8539
Chief Operating Officer
(403) 538-1936
Source:
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