JOURNEY ENERGY INC. 2023 Reserve Report Highlights:
- Proved developed producing reserves decreased 7% to 36.9 MMboe, with a corresponding decrease of 25% in NPV@10% to
$361.9 million ($368.4 million including theCountess Power Project (“CPP”)). The PDP reserve life index increased to 8.4 years from 8.3 years. - Proved reserves decreased 2% to 50.0 MMboe, with a corresponding decrease of 17% in NPV@10% to
$504.1 million ($581.5 million including the CPP,Gilby Power Project “GPP”) and Mazeppa power project (“MPP”). - Proved plus Probable Developed Producing reserves decreased 5% to 48.6 MMboe, with a corresponding decrease of 22% in NPV@10% to
$450.5 million ($457.0 million including the CPP). The Proved plus Probable Developed Producing reserve life index increased to 10.8 years from 10.5 years. - Proved plus Probable reserves decreased 1% to 80.4 MMboe, with a corresponding decrease of 14% in NPV@10% to
$772.2 million ($849.6 million including the CPP, GPP and MPP projects). - Proved developed producing and proved plus probable developed producing reserve life index of 8.4 and 10.8 years respectively, are testaments to Journey’s low decline asset base, and the YoY increase in reserve life index demonstrates Journey’s ability to grow our base production base while simultaneously reducing our corporate decline rate.
- Realized attractive F&D and FD&A recycle ratios of 2.4 and 2.5 respectively for proven reserves; and 8.9 and 8.5 respectively for proven plus probable reserves.
- The
$247 million of total proved plus probable undeveloped future development cost (“FDC”) in Journey’s reserve report generates$299 million in future NPV @ 10%. The development wedge generates development cost of approximately$8.25 /boe, a cost which is consistent with Journey’s historical averages.
Unaudited Financial Information and 2023 Update Guidance
The preliminary financial information contained in this press release is not a comprehensive statement of our financial results for the fourth quarter and year ended
COMPANY GROSS WORKING INTEREST OIL AND GAS RESERVES AND NET PRESENT VALUES
The following table provides summary information presented in the
The 2023 GLJ reserve report includes the abandonment and reclamation liability associated with all active and inactive wells, facilities, pipelines and gathering systems.
Detailed reserve information will be presented in the Company’s upcoming Statement of Reserves Data and Other Oil and Gas Information section of the Company’s Annual Information Form scheduled to be filed on SEDAR on or before
Company Gross Reserves
Based on Three Consultants Average Price and Costs as at
| Light/ Medium Oil | Tight Oil | Heavy Oil | Natural Gas | NGL’s | Total(2) | |
| Reserves Category | (Mbbl) | (Mbbl) | (Mbbl) | (MMcf) | (Mbbl) | (Mboe) |
| Proved | ||||||
| Producing | 7,822 | 116 | 9,254 | 95,517 | 3,835 | 36,947 |
| Developed non-producing | 263 | - | 521 | 2,914 | 106 | 1,376 |
| Undeveloped | 2,865 | - | 3,098 | 26,590 | 1,257 | 11,652 |
| Total proved | 10,951 | 116 | 12,873 | 125,021 | 5,198 | 49,975 |
| Probable | 7,191 | 34 | 5,535 | 78,695 | 4,525 | 30,402 |
| Total proved plus probable | 18,142 | 151 | 18,408 | 203,716 | 9,724 | 80,377 |
| Included in Above | ||||||
| Proved plus probable producing | 10,515 | 151 | 11,502 | 128,858 | 4,999 | 48,643 |
Notes:
(1) Company Gross Reserves consists of Journey’s working interest (operated and non-operated) share of reserves before deduction of royalties payable and without including royalties receivable by the Company.
(2) In the case of natural gas volumes, boes are derived by converting natural gas to oil using the ratio of six thousand cubic feet of natural gas to one barrel of oil (6 Mcf:1 bbl).
(3) Total values may not add due to rounding.
Net Present Values of Future Net Revenue (Based on Three Consultants Average Forecast Prices and Costs)
| Before Tax Net Present Value(1) ($000’s) | |||||
| Reserves category | 0% | 5% | 10% | 15% | 20% |
| Proved | |||||
| Producing | 295,958 | 403,659 | 361,865 | 313,670 | 274,349 |
| Developed non-producing | 29,316 | 22,091 | 17,405 | 14,190 | 11,881 |
| Undeveloped | 279,788 | 182,574 | 124,838 | 88,668 | 64,765 |
| Total proved | 605,061 | 608,325 | 504,108 | 416,528 | 350,995 |
| Probable | 698,808 | 409,299 | 268,051 | 189,444 | 141,187 |
| Total proved plus probable | 1,303,869 | 1,017,623 | 772,160 | 605,973 | 492,182 |
| Included in Above | |||||
| Proved plus probable producing | 562,812 | 546,891 | 450,543 | 374,276 | 318,755 |
Notes:
(1) The net present values presented in the above table do not include any value associated with the Power Projects.
(2) Forecast pricing used is the average of the published price forecasts for
(3) It should not be assumed that the net present values of future net revenues estimated by GLJ represent fair market value of the reserves. There is no assurance that the forecast price and cost assumptions will be attained and variances could be material.
(4) Total values may not add due to rounding.
The forecast prices and foreign exchange rates used in the GLJ Report are as follows:
| WTI Cushing ($US/bbl) | 40 API ($CDN/bbl) | WCS Crude Oil Stream ($CDN/bbl) | AECO-spot ($CDN/Mmbtu) | NYMEX ($US/Mmbtu) | Foreign Exchange ($US/$CDN) | |
| 2024 | 73.67 | 92.91 | 76.74 | 2.20 | 2.75 | 0.752 |
| 2025 | 74.98 | 95.04 | 79.77 | 3.37 | 3.64 | 0.752 |
| 2026 | 76.14 | 96.07 | 81.12 | 4.05 | 4.02 | 0.755 |
| 2027 | 77.66 | 97.99 | 82.88 | 4.13 | 4.10 | 0.755 |
| 2028 | 79.22 | 99.95 | 85.04 | 4.21 | 4.18 | 0.755 |
| 2029 | 80.80 | 101.95 | 86.74 | 4.30 | 4.27 | 0.755 |
| 2030 | 82.42 | 103.98 | 88.48 | 4.38 | 4.35 | 0.755 |
| 2031 | 84.06 | 106.07 | 90.24 | 4.47 | 4.44 | 0.755 |
| 2032 | 85.75 | 108.18 | 92.04 | 4.56 | 4.53 | 0.755 |
| 2033 | 87.46 | 110.35 | 93.89 | 4.65 | 4.62 | 0.755 |
| 2034 | 89.21 | 112.56 | 95.77 | 4.74 | 4.71 | 0.755 |
| 2035 | 90.99 | 114.81 | 97.68 | 4.84 | 4.80 | 0.755 |
| 2036 | 92.82 | 117.10 | 99.63 | 4.94 | 4.90 | 0.755 |
| 2037 | 94.67 | 119.44 | 101.63 | 5.03 | 5.00 | 0.755 |
| 2038 | 96.56 | 121.83 | 103.66 | 5.13 | 5.10 | 0.755 |
| Thereafter | +2.0%/yr | +2.0%/yr | +2.0%/yr | +2.0%/yr | +2.0%/yr |
Reserves Reconciliation
The following table sets out the reconciliation of Journey’s total gross reserves based on forecast prices and costs by principal product type as at
| Proved (Mboe) | Probable (Mboe) | ||
| 50,813 | 30,159 | 80,972 | |
| Discoveries | - | - | - |
| Extensions | 1,608 | 99 | 1,707 |
| Infill drilling | - | - | - |
| Improved recovery | 1,634 | 959 | 2,594 |
| Technical revisions | 254 | (882) | (628) |
| Acquisitions | 197 | 79 | 276 |
| Dispositions | (22) | (5) | (27) |
| Economic factors | (46) | (9) | (55) |
| Production | (4,463) | - | (4,463) |
| 49,975 | 30,402 | 80,377 |
FINDING, DEVELOPMENT AND ACQUISITION COSTS
Journey’s finding and development (“F&D”) and finding, development and acquisition (“FD&A”) costs for 2023, 2022 and the three-year average are presented in the tables below. The capital costs used in the calculations are those costs related to: land acquisition and retention, seismic, drilling, completions, tangible well site, tie-ins, and facilities, plus the change in estimated future development costs (“FDC”) as per the independent evaluator’s reserve report. Net acquisition costs are the cash outlays in respect of acquisitions; minus the proceeds from the disposition of properties during the year. Due to the timing of capital costs and the subjectivity in the estimation of future costs, the aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated FDC’s generally will not necessarily reflect total FDC’s related to reserve additions for that year. The reserves used in this calculation are working interest reserve additions, including technical revisions and changes due to economic factors. The 2023 and the three-year average capital expenditures are currently unaudited as the 2023 financial results are in the process of being finalized. For the unaudited information see the reconciliation of the capital expenditures below which are as of the date of this press release.
| Proved Finding, Development & Acquisition Costs | 2023 | 2022 | 3 Year |
| Capital expenditures (including A&D) ($000’s) | 26,400 | 178,030 | 215,142 |
| Change in future capital ($000’s) | 15 | 44,714 | 52,194 |
| Total capital for FD&A (000’s) | 26,415 | 222,744 | 267,336 |
| Reserve additions, including A&D (Mboe) | 3,625 | 21,178 | 31,726 |
| Proved FD&A costs – including changes in future capital ($/boe) | 7.29 | 10.52 | 8.43 |
| Proved FD&A costs – excluding changes in future capital ($/boe) | 7.28 | 8.41 | 6.78 |
| Recycle ratio(1) | |||
| Including changes in future capital | 2.5 | 3.0 | 2.7 |
| Proved plus Probable Finding, Development & Acquisition Costs | 2023 | 2022 | 3 Year |
| Capital expenditures (including A&D) ($000’s) | 26,400 | 178,030 | 215,142 |
| Change in future capital ($000’s) | (18,203) | 90,257 | 86,860 |
| Total capital for FD&A ($000’s) | 8,197 | 268,287 | 302,002 |
| Reserve additions, including A&D (Mboe) | 3,867 | 29,753 | 41,318 |
| Proved FD&A costs – including changes in future capital ($/boe) | 2.12 | 9.02 | 7.31 |
| Proved FD&A costs – excluding changes in future capital ($/boe) | 6.83 | 5.98 | 5.21 |
| Recycle ratio(1) | |||
| Including changes in future capital | 8.5 | 3.5 | 3.1 |
| Proved Finding & Development Costs | 2023 | 2022 | 3 Year |
| Capital expenditures (excluding A&D) ($000’s) | 25,469 | 41,577 | 70,036 |
| Change in future capital ($000’s) | (23) | 11,433 | 18,379 |
| Total capital for F&D (000’s) | 25,446 | 53,010 | 88,415 |
| Reserve additions, excluding A&D (Mboe) | 3,428 | 3,636 | 11,800 |
| Proved F&D costs – including changes in future capital ($/boe) | 7.42 | 14.58 | 7.49 |
| Proved F&D costs – excluding changes in future capital ($/boe) | 7.43 | 11.43 | 5.94 |
| Recycle ratio(1) | |||
| Including changes in future capital | 2.4 | 2.2 | 3.0 |
| Proved plus Probable Finding & Development Costs | 2023 | 2022 | 3 Year |
| Capital expenditures (excluding A&D) ($000’s) | 25,469 | 41,577 | 70,036 |
| Change in future capital ($000’s) | (18,241) | 31,654 | 27,623 |
| Total capital for F&D (000’s) | 7,228 | 73,231 | 97,659 |
| Reserve additions, excluding A&D (Mboe) | 3,591 | 5,951 | 14,596 |
| Proved F&D costs – including changes in future capital ($/boe) | 2.01 | 12.31 | 6.69 |
| Proved F&D costs – excluding changes in future capital ($/boe) | 7.09 | 6.99 | 4.80 |
| Recycle ratio(1) | |||
| Including changes in future capital | 8.9 | 2.6 | 3.4 |
Notes:
(1) Recycle ratio is calculated as the operating netback per boe divided by F&D or FD&A costs per boe as applicable. The operating netbacks used in the respective years are as follows: 2023 (unaudited) -
(2) Future Development Costs have been adjusted for the effects of reserves categorized as acquisitions and dispositions.
FUTURE DEVELOPMENT COSTS
The following table provides the breakdown of future development costs deducted in the estimation of the future net revenue attributable to the proved and proved plus probable reserve categories noted below:
($000’s) | Proved | Proved plus Probable |
| 2024 | 13,920 | 16,058 |
| 2025 | 48,068 | 75,879 |
| 2026 | 36,399 | 88,272 |
| 2027 | 20,727 | 41,551 |
| 2028 | 14,143 | 29,987 |
| Remaining | 9,089 | 23,065 |
| Total (Undiscounted) | 142,346 | 274,812 |
RESERVE LIFE INDEX
The Company’s reserve life index (“RLI”) is calculated by taking the Company Gross Reserves from the GLJ Report and dividing them by the projected 2024 production as estimated in the GLJ Report.
| Company Gross Reserves | 2024 Company Gross Production | RLI | |
| Reserves Category | (Mboe) | (Mboe) | (Years) |
| Proved, developed, producing | 36,947 | 4,395 | 8.4 |
| Total proved | 49,975 | 4,544 | 11.0 |
| Proved plus probable producing | 48,643 | 4,514 | 10.8 |
| Proved plus probable | 80,377 | 4,707 | 17.1 |
NET ASSET VALUE
The following table provides a calculation of Journey’s estimated net asset value (“NAV”) and net asset value per share (“NAVPS”) as at
| Net Asset Value ($000’s) | Net Asset Value ($/share) | |||||||
| Category | 2023 | 2022 | % | 2023 | 2022 | % | ||
| PDP plus CPP (developed) | 306,698 | 392,085 | (22) | 5.00 | 6.77 | (26 | ) | |
| TP plus CPP, GPP & MPP (developed + undeveloped) | 519,819 | 540,829 | (4) | 8.47 | 9.34 | (9 | ) | |
| P+P DP plus CPP (developed) | 395,298 | 488,596 | (19) | 6.44 | 8.44 | (24 | ) | |
| 787,919 | 830,867 | (5) | 12.84 | 14.35 | (11 | ) | ||
Notes:
(1) Aggregate NAV is calculated by taking the future net revenues per the GLJ report, on a before tax basis, discounted at 10% and subtracting net debt at
(2) Year-end NAVPS is calculated by taking the NAV and dividing it by the basic shares outstanding as at
OPERATIONS UPDATE
Journey is happy to report that it has now completed expenditures and obligations in association with the
About the Company
Journey is a Canadian exploration and production company focused on oil-weighted operations in western
For further information contact:
| or | ||
| President and Chief Executive Officer | Chief Financial Officer | |
| 403.303.3232 | 403.303.3238 | |
| alex.verge@journeyenergy.ca | gerry.gilewicz@journeyenergy.ca | |
| 700, 517 – 10thAvenue SW | ||
| 403.294.1635 | ||
| www.journeyenergy.ca |
ADVISORIES
This press release contains forward-looking statements and forward-looking information (collectively "forward looking information") within the meaning of applicable securities laws relating to the Company’s plans and other aspects of our anticipated future operations, management focus, strategies, financial, operating and production results, industry conditions, commodity prices and business opportunities. In addition, and without limiting the generality of the foregoing, this press release contains forward-looking information regarding decline rates, anticipated netbacks, drilling inventory, estimated average drill, complete and equip and tie-in costs, anticipated potential of the Assets including, but not limited to, EOR performance and opportunities, capacity of infrastructure, potential reduction in operating costs, production guidance, total payout ratio, capital program and allocation thereof, future production, decline rates, funds flow, net debt, net debt to funds flow, exchange rates, reserve life, development and drilling plans, well economics, future cost reductions, potential growth, and the source of funding our capital spending. Forward-looking information typically uses words such as "anticipate", "believe", "project", "expect", "goal", "plan", "intend" or similar words suggesting future outcomes, statements that actions, events or conditions "may", "would", "could" or "will" be taken or occur in the future.
The forward-looking information is based on certain key expectations and assumptions made by our management, including expectations and assumptions concerning prevailing commodity prices and differentials, exchange rates, interest rates, applicable royalty rates and tax laws; future production rates and estimates of operating costs; performance of existing and future wells; reserve and resource volumes; anticipated timing and results of capital expenditures; the success obtained in drilling new wells; the sufficiency of budgeted capital expenditures in carrying out planned activities; the timing, location and extent of future drilling operations; the state of the economy and the exploration and production business; results of operations; performance; business prospects and opportunities; the availability and cost of financing, labour and services; the impact of increasing competition; the ability to efficiently integrate assets and employees acquired through acquisitions, including the Acquisition, the ability to market oil and natural gas successfully and our ability to access capital. Although we believe 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 Journey can give no assurance that they will prove to be correct. Since forward-looking information addresses future events and conditions, by its very nature they involve inherent risks and uncertainties. Our actual results, performance or achievement could differ materially from those expressed in, or implied by, the forward-looking information and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking information will transpire or occur, or if any of them do so, what benefits that we will derive therefrom. Management has included the above summary of assumptions and risks related to forward-looking information provided in this press release in order to provide security holders with a more complete perspective on our future operations and such information may not be appropriate for other purposes.
Readers are cautioned that the foregoing lists of factors are not exhaustive. Additional information on these and other factors that could affect our operations or financial results are included in reports on file with applicable securities regulatory authorities and may be accessed through the SEDAR website (www.sedar.com).These forward looking statements are made as of the date of this press release and we disclaim any intent or obligation to update publicly any forward-looking information, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
This press release contains future-oriented financial information and financial outlook information (collectively, "FOFI") about Journeys prospective results of operations, funds flow, netbacks, debt, payout ratio well economics and components thereof, all of which are subject to the same assumptions, risk factors, limitations and qualifications as set forth in the above paragraphs. FOFI contained in this press release was made as of the date of this press release and was provided for providing further information about Journey’s anticipated future business operations. Journey disclaims any intention or obligation to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law. Readers are cautioned that the FOFI contained in this press release should not be used for purposes other than for which it is disclosed herein. Information in this press release that is not current or historical factual information may constitute forward-looking information within the meaning of securities laws, which involves substantial known and unknown risks and uncertainties, most of which are beyond the control of Journey, including, without limitation, those listed under “Risk Factors” and “Forward Looking Statements” in the Annual Information Form filed on www.SEDAR.com on
Non-IFRS Measures
The Company uses the following non-IFRS measures in evaluating corporate performance. These terms do not have a standardized meaning prescribed by International Financial Reporting Standards and therefore may not be comparable with the calculation of similar measures by other companies.
1) “Netback(s)”. The Company uses netbacks to help evaluate its performance, leverage, and liquidity; comparisons with peers; as well as to assess potential acquisitions. Management considers netbacks as a key performance measure as it demonstrates the Company’s profitability relative to current commodity prices. Management also uses them in operational and capital allocation decisions. Journey uses netbacks to assess its own performance and performance in relation to its peers. These netbacks are operating, Funds Flow and net income (loss). “Operating netback” is calculated as the average sales price of the commodities sold (excluding financial hedging gains and losses), less royalties, transportation costs and operating expenses. There is no GAAP measure that is reasonably comparable to netbacks. Below is the reconciliation of the Operating Netback for Journey for 2023, 2022 and the three year average:
| $000’s | $/boe | |||||||||||
| 2023 | 2022 | 3 Year | 2023 | 2022 | 3 Year | |||||||
| Revenues | 224,353 | 235,583 | 583,779 | 49.50 | 66.01 | 52.96 | ||||||
| Royalties | (46,980) | (46,976) | (113,166) | (10.37) | (13.16) | (10.27) | ||||||
| Operating expenses | (91,577) | (72,356) | (211,977) | (20.20) | (20.27) | (19.23) | ||||||
| Transportation | (4,325) | (2,485) | (8,195) | (0.95) | (0.70) | (0.74) | ||||||
| Operating netback | 81,491 | 113,766 | 250,451 | 17.98 | 31.88 | 22.72 | ||||||
2) “Net debt” is calculated by taking current assets and then subtracting accounts payable and accrued liabilities; the principal amount of term debt; and the carrying value of the other liability. Net debt is used to assess the capital efficiency, liquidity and general financial strength of the Company. In addition, it is used as a comparison tool to assess financial strength in relation to Journey’s peers.
| Net Debt Reconciliation ($000’s) | 2023 | 2022 | ||
| Principal amount of term debt | 43,763 | 67,580 | ||
| Principal amount of vendor-take-back debt | 17,000 | 43,000 | ||
| Accounts payable and accrued liabilities | 47,214 | 45,495 | ||
| Principal amount of contingent bank debt | - | 5,000 | ||
| Other loans | 419 | 419 | ||
| Deduct: | ||||
| Cash in bank | (17,715) | (31,400) | ||
| Accounts receivable | (24,734) | (29,677) | ||
| Prepaid expenses | (4,271) | (1,650) | ||
| Net debt | 61,676 | 98,767 | ||
3) Journey uses “Capital Expenditures (excluding A&D)” and “Capital Expenditures (including A&D)” to measure its capital investment level compared to the Company’s annual budgeted capital expenditures for its organic capital program, excluding acquisitions or dispositions. The directly comparable GAAP measure to capital expenditures is cash used in investing activities. Journey then adjusts its capital expenditures for A&D activity to give a more complete analysis for its capital spending used for FD&A purposes. The capital spending for A&D proposes has been adjusted to reflect the non-cash component of the consideration paid (i.e. shares issued). The following table details the composition of capital expenditures and its reconciliation to cash flow used in investing activities:
| (000’s) | Year ended | |
| 2023 | 2022 | |
| Land and lease rentals | 1,740 | 919 |
| Geological and geophysical | 351 | 63 |
| Drilling and completions | 15,620 | 31,260 |
| Well equipment and facilities | 7,758 | 9,335 |
| Capital Expenditures (excluding A&D) | 25,469 | 41,577 |
| Corporate acquisition (cash less working capital assumed) | - | 8,226 |
| Corporate acquisition - shares | - | 10,920 |
| Asset acquisitions – cash | 6,467 | 120,307 |
| Asset dispositions - cash | (5,536) | (3,000) |
| Capital Expenditures (including A&D ) | 26,400 | 178,030 |
| Other capital – power generation | 14,456 | 2,996 |
Measurements
All dollar figures included herein are presented in Canadian dollars, unless otherwise noted.
Where amounts are expressed in a barrel of oil equivalent (“boe”), or barrel of oil equivalent per day (“boe/d”), natural gas volumes have been converted to barrels of oil equivalent at nine (6) thousand cubic feet (“Mcf”) to one (1) barrel. Use of the term boe may be misleading particularly if used in isolation. The boe conversion ratio of 6 Mcf to 1 barrel (“Bbl”) of oil or natural gas liquids is based on an energy equivalency conversion methodology primarily applicable at the burner tip, and does not represent a value equivalency at the wellhead. This conversion conforms to the Canadian Securities Regulators’ National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities.
Reserves Disclosure
Journey’s Statement of Reserves Data and Other Oil and Gas Information on Form 51-101F1 dated effective as at
All reserves values, future net revenue and ancillary information contained in this press release are derived from the GLJ Report unless otherwise noted. All reserve references in this press release are “Company gross reserves”. Company gross reserves are the Company’s total working interest reserves before the deduction of any royalties payable by the Company. Estimates of reserves and future net revenue for individual properties may not reflect the same level of confidence as estimates of reserves and future net revenue for all properties, due to the effect of aggregation. There is no assurance that the forecast price and cost assumptions applied by GLJ in evaluating Journey’s reserves will be attained and variances could be material. All reserves assigned in the GLJ Report are located in the Province of
All evaluations and summaries of future net revenue are stated prior to the provision for interest, debt service charges or general and administrative expenses and after deduction of royalties, operating costs, estimated well abandonment and reclamation costs and estimated future capital expenditures. It should not be assumed that the estimates of future net revenues presented in the tables below represent the fair market value of the reserves. The recovery and reserve estimates of Journey’s oil, NGLs and natural gas reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual oil, natural gas and NGL reserves may be greater than or less than the estimates provided herein. There are numerous uncertainties inherent in estimating quantities of crude oil, reserves and the future cash flows attributed to such reserves. The reserve and associated cash flow information set forth herein are estimates only.
Proved reserves are those reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated proved reserves. Probable reserves are those additional reserves that are less certain to be recovered than proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated proved plus probable reserves. Proved developed producing reserves are those reserves that are expected to be recovered from completion intervals open at the time of the estimate. These reserves may be currently producing or, if shut-in, they must have previously been on production, and the date of resumption of production must be known with reasonable certainty. Undeveloped reserves are those reserves expected to be recovered from known accumulations where a significant expenditure (e.g., when compared to the cost of drilling a well) is required to render them capable of production. They must fully meet the requirements of the reserves category (proved or probable) to which they are assigned. Certain terms used in this press release but not defined are defined in NI 51-101, CSA Staff Notice 51-324 – Revised Glossary to NI 51-101, Revised Glossary to NI 51-101, Standards of Disclosure for Oil and Gas Activities (“CSA Staff Notice 51-324”) and/or the COGEH and, unless the context otherwise requires, shall have the same meanings herein as in NI 51-101, CSA Staff Notice 51-324 and the COGEH, as the case may be.
Drilling Locations
This press release discloses drilling inventory in two categories: (a) proved locations; and (b) probable locations. Proved locations and probable locations are derived from the GLJ Report and account for drilling locations that have associated proved and/or probable reserves, as applicable.
Of the 99 net total booked drilling locations identified herein, 47 are net proved locations and 52 are net probable locations.
“Development capital” means the aggregate exploration and development costs incurred in the financial year on reserves that are categorized as development. Development capital excludes capitalized administration costs.
“FDC” Future development costs are the future capital cost estimated for each respective category in year- end reserves attributed with realizing those reserves and associated future net revenue.
“Finding and development costs” Journey calculates F&D costs, including FDC, as the sum of “Capital Expenditures, before A&D” (as defined under “Non-GAAP Measures”) and the change in FDC required to bring the reserves on production, divided by the change in reserves within the applicable reserves category. Management uses F&D costs as a measure of capital efficiency for organic reserves development.
“F&D Cost per BOE” are the F&D costs divided by the change in gross company interest reserves volumes that are characterized as exploration or development, excluding volumes associated with acquisitions, for the period.
“Finding, development and acquisition costs” Journey calculates FD&A costs, including FDC, as the sum of “Capital Expenditures, excluding A&D” and “Capital Expenditures, including A&D” (as defined under “Non-IFRS Measures”), and the change in FDC required to bring the reserves on production, divided by the change in reserves within the applicable reserves category, inclusive of changes due to acquisitions and dispositions. Management uses FD&A costs as a measure of capital efficiency for organic and acquired reserves development.
“FD&A Cost per BOE” is the FD&A cost divided by the change in gross company interest reserves volumes, including changes in volumes characterized as acquisitions or divestitures, in the current period.
Readers are cautioned that the aggregate of capital expenditures incurred in the year, comprised of exploration and development costs and acquisition costs, and the change in estimated FDC generally will not reflect total F&D or FD&A costs related to reserves additions in the year.
Abbreviations
The following abbreviations are used throughout these MD&A and have the ascribed meanings:
| A&D | acquisition and divestiture of petroleum and natural gas assets |
| API | |
| bbl | Barrel |
| bbls | Barrels |
| boe | barrels of oil equivalent (see conversion statement below) |
| boe/d | barrels of oil equivalent per day |
| gj | Gigajoules |
| GAAP | Generally Accepted Accounting Principles |
| IFRS | International Financial Reporting Standards |
| Mbbls | thousand barrels |
| Mboe | thousand boe |
| Mcf | thousand cubic feet |
| Mmcf | million cubic feet |
| Mmcf/d | million cubic feet per day |
| MSW | Mixed sweet |
| MW | One million watts of power |
| NGL’s | natural gas liquids (ethane, propane, butane and condensate) |
| WCS | Western Canada Select benchmark oil price. This crude oil is heavy/sour with API gravity of 19-22 degrees and sulphur content of 1.8-3.2%. |
| WTI | West Texas Intermediate benchmark Oil price. This crude oil is light/sweet with API gravity of 39.6 degrees and sulfur content of 0.24%. |
All volumes in this press release refer to the sales volumes of crude oil, natural gas and associated by-products measured at the point of sale to third-party purchasers. For natural gas, this occurs after the removal of natural gas liquids.
No securities regulatory authority has either approved or disapproved of the contents of this press release.
2024 GlobeNewswire, Inc., source
