Exhibit 99.6
INFORMATION ABOUT NRO
Description of the Business
Certain aspects of the presentation of the results of operations of Nickel Road Operating LLC, a Delaware limited liability company, and its subsidiaries (herein referred to collectively as “NRO”), have been conformed for purposes of presenting comparable results. For full historical financial statements of NRO for the periods presented, please see the financial statements of NRO for the nine months ended September 30, 2024 and for the year ended December 31, 2023 previously filed.
NRO is a private, independent, and private equity backed exploration and production company founded in 2017. NRO focuses on the acquisition, development, and production of oil and natural gas reserves in Weld County, Colorado, in the Greater Wattenberg Field of Colorado’s Denver-Julesburg Basin (the “DJ Basin”). NRO has developed its acreage by drilling horizontal wells targeting the Codell and Niobrara formations. As of December 31, 2023, NRO operated 26 wells in the DJ Basin and maintained 90 operated well permits issued by the Colorado Energy and Carbon Management Commission (“CECMC”) to drill undeveloped locations. Net production from NRO’s properties for the nine months ended September 30, 2024, was approximately 2,300 Boe per day, of which 63% was oil. According to a report prepared by Cawley, Gillespie & Associates, Inc. (“CG&A”), total proved reserves associated with NRO’s properties were 16.4 MMboe as of December 31, 2023, of which 31% were proved developed. NRO’s operations are all conducted onshore in the United States. On October 1, 2024, Prairie Operating Co. (“Prairie”), completed the previously announced $84.5 million acquisition of NRO’s oil-weighted assets (the “NRO Acquisition”).
Management’s Discussion and Analysis of Financial Condition and Results of Operations of Nickel Road Operating LLC
General and Basis of Presentation
NRO derived substantially all of its revenue from the sale of oil, natural gas and NGLs that are produced from interests in its properties. Oil, natural gas and NGL prices are inherently volatile and are influenced by many factors outside of NRO’s control. To achieve more predictable cash flows and to reduce its exposure to downward price fluctuations, NRO has historically used derivative instruments to hedge future sales prices and basis differentials on a portion of its oil, natural gas and NGL production. In January 2024, in connection with the Asset Purchase Agreement, dated January 11, 2024, by and among Prairie, Prairie LLC, Nickel Road Operating LLC and Nickel Road Development LLC (the “NRO Agreement”), NRO liquidated all of its outstanding hedges. NRO’s historical commodity derivative instruments include swaps and costless collars. NRO’s derivative strategy, including the volumes and commodities covered and the relevant fixed and market prices, was based in part on NRO’s management’s view of expected future market conditions, capital spending plans, and analysis of well-level economic return potential.
NRO focused its efforts on increasing oil, natural gas and NGLs production and reserves while controlling costs at a level that is appropriate for long-term sustainable operations. NRO’s future earnings and cash flows are dependent on its ability to manage revenues and overall cost structure at a level that allows for profitable production.
Divestiture of assets and acreage in 2022 and 2023
In July 2022, NRO closed on the divestiture of upstream assets including 2,752 net acres, 321 net royalty acres, and 17 producing horizontal wells (5 operated and 12 non-operated, royalty or overriding royalty) for $64 million (the “2022 NRO Divestiture”). The divested assets produced 672 Boe per day for the six months ended June 30, 2022, with total proved reserves of 3,024 Mboe as of December 31, 2021. This transaction is described further in NRO’s financial statements and footnotes.
In August 2023, NRO closed on the divestiture of upstream assets including 896 net royalty acres for $7 million (the “2023 NRO Divestiture” and, together with the 2022 NRO Divestiture, the “NRO Divestitures”). The divested assets produced 86 Boe per day in the seven months ended July 31, 2023, with 253 Mboe of proved reserves as of December 31, 2022. This transaction is described further in NRO’s financial statements and footnotes.
Overview
The following table presents NRO’s production volumes and financial highlights, inclusive of assets sold in the NRO Divestitures through the date of sale, for the nine months ended September 30, 2024 and 2023:
| | | Nine Months Ended September 30, | |
| | | 2024 | | | 2023 | |
| | | Period Total | | | Per Day | | | Period Total | | | Per Day | |
| Production Sales Volume Data: | | | | | | | | | | | | | | | | |
| Oil (Mbbls) | | | 398 | | | | 1.5 | | | | 439 | | | | 1.6 | |
| Gas (MMcf) | | | 794 | | | | 2.9 | | | | 585 | | | | 2.1 | |
| NGLs (Mbbls) | | | 102 | | | | 0.4 | | | | 105 | | | | 0.4 | |
| Financial Data (thousands): | | | | | | | | | | | | | | | | |
| Revenue | | $ | 30,781 | | | | | | | $ | 34,210 | | | | | |
| (Loss) income from operations | | $ | (18,789 | ) | | | | | | $ | 11,520 | | | | | |
NRO’s revenues for the nine months ended September 30, 2024 decreased by $3.4 million compared to the nine months ended September 30, 2023, primarily due to a slight decrease in commodity prices and production volumes. NRO’s income from operations for the nine months ended September 30, 2024 decreased by $30.3 million compared to the nine months ended September 30, 2023, mostly due to an impairment of oil and gas properties in the nine months ended September 30, 2024.
Results of Operations
Nine Months Ended September 30, 2024 vs. Nine Months Ended September 30, 2023
| | | Nine Months Ended September 30, | |
| | | 2024 | | | 2023 | | | $ Change | | | % Change | |
| | | (Thousands) | | | | | | | |
| Revenues: | | | | | | | | | | | | | | | | |
| Oil revenue | | $ | 29,820 | | | $ | 32,800 | | | $ | (2,980 | ) | | | (9 | )% |
| Gas revenue | | | 344 | | | | 521 | | | | (178 | ) | | | (34 | )% |
| NGL revenue | | | 617 | | | | 889 | | | | (272 | ) | | | (31 | )% |
| Total revenues | | $ | 30,781 | | | $ | 34,210 | | | $ | (3,429 | ) | | | (10 | )% |
Oil Revenue
Oil revenues for the nine months ended September 30, 2024 decreased $3.0 million, or 9%, from the nine months ended September 30, 2023, related to lower oil production and partially offset by higher oil prices. The following table reflects oil prices, the price impact of NRO’s derivative settlements and oil production volumes for the nine months ended September 30, 2024 and 2023.
| | | Nine Months Ended September 30, | |
| | | 2024 | | | 2023 | |
| Oil revenue (per barrel) | | $ | 74.94 | | | $ | 74.69 | |
| Impact of net cash (paid) received related to settlement of derivatives (per barrel)(1) | | | 0.56 | | | | (1.58 | ) |
| Oil net price including all derivative settlements (per barrel) | | $ | 75.50 | | | $ | 73.11 | |
| Oil production volumes (Mbbls) | | | 398 | | | | 439 | |
| Per day oil production volumes (Mbbls/d) | | | 1.5 | | | | 1.6 | |
| (1) | Included in net gain (loss) on derivatives on the Condensed Consolidated Statements of Operations. |
Gas Revenue
Natural gas revenue for the nine months ended September 30, 2024 decreased $0.2 million, or 34%, from the nine months ended September 30, 2023, related to lower natural gas sales prices, partially offset by higher production. The following table reflects natural gas prices, the price impact of NRO’s derivative settlements and natural gas production volumes for the nine months ended September 30, 2024 and 2023.
| | | Nine Months Ended September 30, | |
| | | 2024 | | | 2023 | |
| Natural gas revenue (per Mcf) | | $ | 0.43 | | | $ | 0.89 | |
| Impact of net cash (paid) received related to settlement of derivatives (per Mcf)(1) | | | — | | | | (0.16 | ) |
| Natural gas net price including all derivative settlements (per Mcf) | | $ | 0.43 | | | $ | 0.73 | |
| Natural gas production volumes (MMcf) | | | 794 | | | | 585 | |
| Per day natural gas production volumes (MMcf/d) | | | 2.9 | | | | 2.1 | |
| (1) | Included in net gain (loss) on derivatives on the Condensed Consolidated Statements of Operations. |
NGL revenue
NGL revenue for the nine months ended September 30, 2024 decreased $0.3 million, or 31%, from the nine months ended September 30, 2023, related to lower sales prices and lower production. The following table reflects NGL prices and NGL production volumes for the nine months ended September 30, 2024 and 2023. NRO did not have any derivative settlements related to its NGL volumes for the nine months ended September 30, 2024 and 2023.
| | | Nine Months Ended September 30, | |
| | | 2024 | | | 2023 | |
| NGL revenue (per barrel) | | $ | 6.05 | | | $ | 8.47 | |
| NGL production volumes (Mbbls) | | | 102 | | | | 105 | |
| Per day NGL production volumes (Mbbls/d) | | | 0.4 | | | | 0.4 | |
Operating expenses and (loss) income from operations analysis:
| | | Nine Months Ended September 30, | | | | | | | | | Per Boe (1) Expense | |
| | | 2024 | | | 2023 | | | $ Change | | | % Change | | | 2024 | | | 2023 | |
| | | (Thousands) | | | | | | | | | (Thousands) | |
| Operating Expenses: | | | | | | | | | | | | | | | | | | | | | | | | |
| Lease operating expenses | | $ | 4,169 | | | $ | 3,317 | | | $ | 852 | | | | 26 | % | | $ | 6.59 | | | $ | 5.17 | |
| Production taxes | | | 1,939 | | | | 3,422 | | | | (1,483 | ) | | | (43 | )% | | | 3.07 | | | | 5.33 | |
| Depletion, depreciation, and amortization | | | 10,726 | | | | 12,853 | | | | (2,127 | ) | | | (17 | )% | | | 16.97 | | | | 20.03 | |
| General and administrative | | | 3,018 | | | | 3,099 | | | | (81 | ) | | | (3 | )% | | | 4.77 | | | | 4.83 | |
| Impairment | | | 29,719 | | | | - | | | | 29,719 | | | | NM | | | | 47.01 | | | | - | |
| Total operating expenses | | $ | 49,571 | | | $ | 22,691 | | | $ | 26,880 | | | | 118 | % | | $ | 78.41 | | | $ | 35.36 | |
| (Loss) income from operations | | $ | (18,789 | ) | | $ | 11,520 | | | $ | (30,309 | ) | | | NM | | | $ | (29.72 | ) | | $ | 17.95 | |
| (1) | “Boe” means barrel of oil equivalent, using the ratio of six Mcf of natural gas to one barrel of crude oil or condensate. |
| NM: | A percentage calculation is not meaningful due to change in signs, a zero-value denominator, or a percentage change greater than 200. |
Lease operating expenses increased $0.9 million for the nine months ended September 30, 2024 compared to the nine months ended September 30, 2023, related to increased operating activity and service cost inflation.
Production taxes decreased $1.5 million for the nine months ended September 30, 2024 compared to the nine months ended September 30, 2023, due to lower revenue from lower commodity prices and lower oil sales volumes.
Depletion, depreciation and amortization decreased $2.1 million for the nine months ended September 30, 2024 compared to the nine months ended September 30, 2023, primarily related to lower property base from impairments in 2023 and lower proved reserves resulting from lower commodity prices.
General and administrative expenses decreased $0.1 million for the nine months ended September 30, 2024 compared to the nine months ended September 30, 2023, related to lower expenses incurred on labor-related costs.
Impairment increased $29.7 million for the nine months ended September 30, 2024 compared to the nine months ended September 30, 2023, related to the NRO Acquisition.
Results below included in (loss) income from operations:
| | | Nine Months Ended September 30, | | | | | | | |
| | | 2024 | | | 2023 | | | $ Change | | | % Change | |
| | | (Thousands) | | | | | | | |
| (Loss) income from operations | | $ | (18,789 | ) | | $ | 11,520 | | | $ | (30,309 | ) | | | NM | |
| Loss on commodity derivatives | | | (47 | ) | | | (472 | ) | | | 425 | | | | (90 | )% |
| Net interest expense | | | (975 | ) | | | (1,525 | ) | | | 550 | | | | (36 | )% |
| Gain on sale of oil and gas properties | | | 5,373 | | | | 6,262 | | | | (889 | ) | | | (14 | )% |
| Other income (expense) | | | 1 | | | | (7 | ) | | | 8 | | | | (114 | )% |
| Net (loss) income | | $ | (14,438 | ) | | $ | 15,777 | | | $ | (30,215 | ) | | | (192 | )% |
| NM: | A percentage calculation is not meaningful due to change in signs, a zero-value denominator, or a percentage change greater than 200. |
NRO had a $0.4 million decrease in derivative instruments for the nine months ended September 30, 2024, compared to the nine months ended September 30, 2023 due to having no outstanding hedges as of September 30, 2024.
The $0.6 million decrease in interest expense for the nine months ended September 30, 2024 compared to the nine months ended September 30, 2023 relates to lower average debt outstanding.
NRO recorded a $5.4 million gain on the sale of oil and gas properties for the nine months ended September 30, 2024, resulting from the NRO Acquisition. For the nine months ended September 30, 2023, NRO recorded a $6.3 million gain on the sale of oil and gas properties resulting from the 2023 NRO Divestiture.
Year ended December 31, 2023 vs. Year ended December 31, 2022
| | | Year ended December 31, | |
| | | 2023 | | | 2022 | | | $ Change | | | % Change | |
| | | (Thousands) | | | | | | | |
| Revenues: | | | | | | | | | | | | | | | | |
| Oil revenue | | $ | 46,309 | | | $ | 57,744 | | | $ | (11,435 | ) | | | (20 | )% |
| Gas revenue | | | 702 | | | | 3,977 | | | | (3,275 | ) | | | (82 | )% |
| NGL revenue | | | 1,158 | | | | 4,339 | | | | (3,181 | ) | | | (73 | )% |
| Total revenues | | $ | 48,169 | | | $ | 66,060 | | | $ | (17,891 | ) | | | (27 | )% |
Oil Revenue
Oil revenues for 2023 decreased $11.4 million, or 20%, from 2022, related to lower oil sales prices and the 2022 NRO Divestiture. The following table reflects oil prices, the price impact of NRO’s derivative settlements and oil production volumes for the year ended December 31, 2023 and 2022.
| | | Year ended December 31, | |
| | | 2023 | | | 2022 | |
| Oil revenue (per barrel) | | $ | 75.06 | | | $ | 93.29 | |
| Impact of net cash (paid) received related to settlement of derivatives (per barrel)(1) | | | (1.60 | ) | | | (32.15 | ) |
| Oil net price including all derivative settlements (per barrel) | | $ | 73.46 | | | $ | 61.14 | |
| Oil production volumes (Mbbls) | | | 617 | | | | 619 | |
| Per day oil production volumes (Mbbls/d) | | | 1.7 | | | | 1.7 | |
| (1) | Included in net gain (loss) on derivatives on the Condensed Consolidated Statements of Operations. |
Gas Revenue
Natural gas revenue for 2023 decreased $3.3 million, or 82%, from 2022, related to lower natural gas sales prices and lower production. The following table reflects natural gas prices, the price impact of NRO’s derivative settlements and natural gas production volumes for the years ended December 31, 2023 and 2022.
| | | Year ended December 31, | |
| | | 2023 | | | 2022 | |
| Natural gas revenue (per Mcf) | | $ | 0.79 | | | $ | 4.32 | |
| Impact of net cash (paid) received related to settlement of derivatives (per Mcf)(1) | | | (0.04 | ) | | | (2.02 | ) |
| Natural gas net price including all derivative settlements (per Mcf) | | $ | 0.75 | | | $ | 2.30 | |
| Natural gas production volumes (MMcf) | | | 888 | | | | 920 | |
| Per day natural gas production volumes (MMcf/d) | | | 2.4 | | | | 2.5 | |
| (1) | Included in net gain (loss) on derivatives on the Condensed Consolidated Statements of Operations. |
NGL revenue
NGL revenue for 2023 decreased $3.2 million, or 73%, from 2022, related to lower sales prices and lower production. The following table reflects NGL prices and NGL production volumes for the years ended December 31, 2023 and 2022. NRO did not have any derivative settlements related to its NGL volumes for the years ended December 31, 2023 and 2022.
| | | Year ended December 31, | |
| | | 2023 | | | 2022 | |
| NGL revenue (per barrel) | | $ | 7.77 | | | $ | 26.78 | |
| NGL net price including all derivative settlements (per barrel) | | $ | 7.77 | | | $ | 26.78 | |
| NGL production volumes (Mbbls) | | | 149 | | | | 162 | |
| Per day NGL production volumes (Mbbls/d) | | | 0.4 | | | | 0.4 | |
Operating expenses and income from operations analysis:
| | | Year ended
December 31, | | | | | | | | | Per Boe Expense | |
| | | 2023 | | | 2022 | | | $ Change | | | % Change | | | 2023 | | | 2022 | |
| | | (Thousands) | | | | | | | | | (Thousands) | |
| Operating Expenses: | | | | | | | | | | | | | | | | | | | | | | | | |
| Lease operating expenses | | $ | 4,616 | | | $ | 3,942 | | | $ | 674 | | | | 17 | % | | $ | 5.05 | | | $ | 4.22 | |
| Production taxes | | | 4,409 | | | | 4,975 | | | | (566 | ) | | | (11 | )% | | | 4.82 | | | | 5.33 | |
| Depletion, depreciation, and amortization | | | 16,116 | | | | 17,760 | | | | (1,644 | ) | | | (9 | )% | | | 17.63 | | | | 19.01 | |
| Impairment | | | 5,078 | | | | 330 | | | | 4,748 | | | | NM | | | | 5.56 | | | | 0.35 | |
| General and administrative | | | 4,068 | | | | 4,260 | | | | (192 | ) | | | (5 | )% | | | 4.45 | | | | 4.56 | |
| Total operating expenses | | $ | 34,287 | | | $ | 31,267 | | | $ | 3,020 | | | | 10 | % | | $ | 37.51 | | | $ | 33.48 | |
| Income from operations | | $ | 13,882 | | | $ | 34,792 | | | $ | (20,910 | ) | | | (60 | )% | | $ | 15.19 | | | $ | 37.25 | |
| NM: | A percentage calculation is not meaningful due to change in signs, a zero-value denominator, or a percentage change greater than 200. |
Lease operating expenses increased $0.7 million for the year ended December 31, 2023, compared to the year ended December 31, 2022, related to increased operating activity, well counts and service cost inflation.
Production taxes decreased $0.6 million for the year ended December 31, 2023, compared to the year ended December 31, 2022, due to lower revenue from lower commodity prices and lower sales volumes.
Depletion, depreciation and amortization decreased $1.6 million for the year ended December 31, 2023, compared to the year ended December 31, 2022, primarily related to lower proved reserves resulting from lower commodity prices.
Impairment increased $4.7 million for the year ended December 31, 2023, compared to the year ended December 31, 2022, related to the NRO Agreement.
General and administrative expenses decreased $0.2 million for the year ended December 31, 2023, compared to the year ended December 31, 2022, related to lower expenses incurred on labor-related costs.
Results below included in income from operations:
| | | Year ended December 31, | | | | | | | |
| | | 2023 | | | 2022 | | | $ Change | | | % Change | |
| | | (Thousands) | | | | | | | |
| Income from operations | | $ | 13,882 | | | $ | 34,792 | | | $ | (20,910 | ) | | | 60 | % |
| Gain on sales of oil and gas properties | | | 5,926 | | | | 25,331 | | | | (19,405 | ) | | | (77 | )% |
| Gain (loss) on commodity derivatives | | | 1,977 | | | | (18,464 | ) | | | 20,441 | | | | NM | |
| Net interest expense | | | (2,011 | ) | | | (895 | ) | | | (1,116 | ) | | | 125 | % |
| Other (expense) income | | | (13 | ) | | | 15 | | | | (28 | ) | | | NM | |
| Net income | | $ | 19,761 | | | $ | 40,779 | | | $ | (21,018 | ) | | | (52 | )% |
| NM: | A percentage calculation is not meaningful due to change in signs, a zero-value denominator, or a percentage change greater than 200. |
NRO recorded a $5.9 million gain on the sale of oil and gas properties for the year ended December 31, 2023, resulting from the 2023 NRO Divestiture. For the year ended December 31, 2022, NRO recorded a $25.3 million gain on the sale of oil and gas properties resulting from the 2022 NRO Divestiture.
NRO had a $20.4 million increase in the gain on derivative instruments for the year ended December 31, 2023, compared to the year ended December 31, 2022, due to decreasing commodity prices.
The $1.1 million increase in interest expense for the year ended December 31, 2023 compared to the year ended December 31, 2022, relates to higher average debt outstanding and an increase in interest rates.
Management’s Discussion and Analysis of Financial Condition and Liquidity
Overview and Liquidity
NRO’s primary sources of liquidity have historically been cash on hand, cash flows from operations, borrowings under its credit facilities and equity provided from investors. NRO expects that a combination of these sources will be sufficient to fund its working capital needs into the future.
Due to the NRO Acquisition, NRO did not drill any wells during the nine months of 2024. In 2023, NRO drilled and completed five wells, and in 2022, also drilled and completed five wells. For the years ended December 31, 2023 and 2022, NRO’s aggregate development, drilling and completion capital expenditures, excluding leasehold and acquisitions and divestitures, were approximately $31.9 million and $34.7 million, respectively.
Credit Facility
Revolving Loan – On February 22, 2021, NRO entered into a revolving loan agreement (the “Loan Agreement”) with UMB Bank, N.A. (“UMB” or the “Lender”), with a maturity of February 22, 2024. The Loan Agreement provides for a maximum revolving loan (the “Revolving Loan”) of $35.0 million with an initial borrowing base of $10.0 million. In October 2022, the Loan Agreement was amended. The total borrowing base and sublimit increased to $30.0 million for the Revolving Loan.
On March 31, 2023, NRO amended its Loan Agreement to provide for a maximum Revolving Loan of $50.0 million which matures on February 22, 2026. As of the date of the amendment the borrowing base was increased to $35.0 million, with a sublimit of $25.0 million, and is subject to regular redeterminations by the Lender. Permitted distributions are subject to limitations defined within the amendment and required hedge transactions are amended such that as of September 30, 2023, and thereafter, so long as the borrowing base utilization exceeds 60%, NRO is required to maintain crude oil hedges of at least 60% of NRO’s anticipated crude oil production for a period of not less than 12 months, to be complied with on a quarterly basis. On August 31, 2023, NRO amended its Loan Agreement to decrease the borrowing base to $33.0 million.
All sums advanced under the Revolving Loan, together with all accrued but unpaid interest thereon, are due in full at maturity. The Loan Agreement requires NRO to maintain certain affirmative and negative covenants, including certain financial ratios defined in the Loan Agreement and second amendment, and provides the Lender with a first security interest in substantially all of NRO’s assets. The interest rate of the Revolving Loan is the lesser of the (1) Wall Street Journal prime rate, plus the applicable margin, or (2) the Maximum Rate as defined per the Loan Agreement. The interest rate as of December 31, 2023, was 9.50%. Commitment fees equal to 0.5% of the undrawn amount are payable quarterly under this agreement.
In conjunction with the NRO Acquisition, NRO liquidated its open hedge positions in January 2024 resulting in net cash proceeds of approximately $223,000. On January 31, 2024, NRO received a waiver of the minimum hedge transaction requirement from the Lender through July 1, 2024. In September 2024, NRO fully repaid the outstanding balance on the Revolving Loan and was fully released from the Revolving Loan effective October 1, 2024.
March 2023 Term Loan – The March 2023 amended Loan Agreement also allows for a new Term Loan (“March 2023 Term Loan”) in the amount of $10.0 million. The March 2023 Term Loan shall be payable in monthly principal installments commencing on August 1, 2023, plus all accrued interest, and matures on July 1, 2024. The March 2023 Term Loan bears interest at a rate equal to the sum of the Prime Rate (as defined in the Loan Agreement), plus the Applicable Margin (as defined in the Loan Agreement); provided, however, that the interest rate on the March 2023 Term Loan shall never fall below 3.75%. As of July 1, 2024, this loan matured and was paid off in full.
September 2021 Term Loan – On September 1, 2021, the Loan Agreement was amended to establish a term loan (“September 2021 Term Loan”) in the amount of $12.0 million that matured on August 31, 2022. The September 2021 Term Loan was payable in monthly principal installments commencing January 31, 2022, plus all accrued interest. Interest for the September 2021 Term Loan was fixed at 5.25%. The September 2021 Term Loan also provides the lender with a first security interest in substantially all of NRO’s assets. As of December 31, 2023, this loan matured and was paid off in full.
Interest expense related to the Revolving Loan and the March 2023 Term Loan for the nine months ended September 30, 2024 and 2023, was approximately $1.0 million and $1.5 million, respectively.
Commodity Price Risk Management
NRO has historically entered into derivative contracts, primarily swaps and collars to hedge future crude oil and natural gas production in order to mitigate the risk of market price fluctuations. All derivative instruments are recorded on the consolidated balance sheets at fair value. NRO has elected not to apply hedge accounting to any of its derivative transactions; consequently, NRO recognizes mark-to-market gains and losses in earnings currently, rather than deferring such amounts in other comprehensive income for those commodity derivatives that qualify as cash flow hedges.
In January 2024, in connection with the NRO Agreement, NRO received a waiver of the minimum hedge and liquidated all of its open hedge positions, resulting in net cash proceeds of approximately $223,000. Therefore, NRO did not have any commodity derivative instruments outstanding as of September 30, 2024.
Sources (Uses) of Cash
| | | Nine Months Ended September 30, | |
| | | 2024 | | | 2023 | |
| | | (Thousands) | |
| Net cash provided by (used in): | | | | | | | | |
| Operating activities | | $ | 19,391 | | | $ | 36,117 | |
| Investing activities | | | 3,455 | | | | (23,565 | ) |
| Financing activities | | | (20,584 | ) | | | (12,130 | ) |
| Increase in cash, cash equivalents and restricted cash | | $ | 2,262 | | | $ | 422 | |
Operating activities:
Net cash provided by operating activities decreased $16.7 million for the nine months ended September 30, 2024 compared to the nine months ended September 30, 2023, primarily due to lower oil sales volumes, natural gas and NGL prices and higher lease operating expenses, partially offset by lower production taxes.
Investing activities:
Net cash provided by investing activities increased by $27.0 million for nine months ended September 30, 2024 compared to the nine months ended September 30, 2023, primarily due to the decrease of drilling and completion capital expenditures of oil and gas properties and leasehold and development capital expenditures of $28.2 million, partially offset by the decrease in proceeds from the sale of oil and gas properties of $1.2 million.
Financing activities:
Net cash used in financing activities during the nine months ended September 30, 2024 includes $20.6 million in net cash repayments on the Revolving Loan related to core business activities borrowings. Net cash used in financing activities during the nine months ended September 30, 2023 includes $12.0 million in net cash repayments on the Revolving Loan related to core business activities.
Critical Accounting Estimates
The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Depreciation, depletion, and amortization of oil and gas properties and the impairment of proved oil and gas properties are determined using estimates of oil and gas reserves. There are numerous uncertainties in estimating the quantity of reserves and in projecting the future rates of production and timing of development expenditures, including future costs to dismantle, dispose, and restore NRO’s properties. Oil and gas reserve engineering must be recognized as a subjective process of estimating underground accumulations of oil and gas that cannot be measured in an exact way.
The more significant reporting areas impacted by management’s judgments and estimates are as follows:
Oil and Gas Properties
NRO accounts for its oil and gas operations using the successful efforts method of accounting. Under this method, all costs associated with property acquisitions, successful exploratory wells, and development wells are capitalized. Items charged to expense generally include geological and geophysical costs, costs of unsuccessful exploratory wells, delay rentals, and oil and gas production costs. Capitalized costs of proved leasehold costs are depleted on a well-by-well basis using the units-of-production method based on total proved developed producing oil and gas reserves. Other capitalized costs of producing properties are also depleted based on total proved developed producing reserves. Depletion expense for the nine months ended September 30, 2024 and 2023 was approximately $10.7 million and $12.9 million, respectively.
NRO assesses its proved oil and gas properties for impairment whenever events or circumstances indicate that the carrying value of the assets may not be recoverable, but at least annually. The impairment test compares undiscounted future net cash flows to the assets’ net book value. If the net capitalized costs exceed future net cash flows, then the cost of the property is written down to the estimated fair value. Fair value for oil and natural gas properties is generally determined based on an analysis of discounted future net cash flows adjusted for certain risk factors.
Unproved properties are assessed periodically on a project-by-project basis to determine whether an impairment has occurred. NRO’s management’s assessment includes consideration of the results of exploration activities, commodity price predictions or forecasts, planned future sales, or expiration of all or a portion of such projects.
At December 31, 2023, NRO’s management determined there was an impairment of $5.1 million related to the NRO Acquisition. At December 31, 2022, NRO’s management determined there was an impairment of $0.3 million related to the expiration of non-core undeveloped leases. An impairment of $29.7 million related to the NRO Acquisition was recognized during the nine months ended September 30, 2024.
Gains and losses arising from sales of oil and gas properties are included in other income. However, a partial sale of proved properties within an existing field that does not significantly affect the unit-of-production depletion rate will be accounted for as a normal retirement with no gain or loss recognized. The sale of a partial interest within a proved property is accounted for as a recovery of cost. The partial sale of unproved property is accounted for as a recovery of cost when there is uncertainty of the ultimate recovery of the cost applicable to the interest retained.
Derivative Instruments
Prior to signing the NRO Agreement, NRO entered into derivative contracts, primarily swaps and collars, to hedge future crude oil and natural gas production in order to mitigate the risk of market price fluctuations. All derivative instruments are recorded on the consolidated balance sheets at fair value. NRO has elected not to apply hedge accounting to any of its derivative transactions; consequently, NRO recognizes mark-to-market gains and losses in earnings currently, rather than deferring such amounts in other comprehensive income for those commodity derivatives that qualify as cash flow hedges.
Revenue Recognition
NRO recognizes revenue in accordance with ASC Topic 606, Revenue from Contracts with Customers. Revenue from the sale of oil, natural gas and NGLs is recognized when the product is delivered to the customers’ custody transfer points, and collectability is reasonably assured. NRO fulfills the performance obligations under the customer contracts through daily delivery of oil, natural gas and NGLs to the customers’ custody transfer points, and revenues are recorded on a monthly basis. The prices received for oil, natural gas and NGLs sales under NRO’s contracts are generally derived from stated market prices, which are then adjusted to reflect deductions, including transportation, fractionation, and processing. As a result, the revenues from the sale of oil, natural gas and NGLs will decrease if market prices decline. The sales of oil, natural gas and NGLs as presented on the condensed consolidated statements of income represent NRO’s share of revenues, net of royalties and excluding revenue interests owned by others. When selling oil, natural gas and NGLs on behalf of royalty owners or working interest owners, NRO acts as an agent and, thus, reports the revenue on a net basis. To the extent actual volumes and prices of oil, natural gas and NGLs sales are unavailable for a given reporting period because of timing or information not received from third parties, the expected sales volumes and prices for those properties are estimated and recorded.
Oil and Gas Data
Costs Incurred
The following table sets forth the costs incurred for property acquisitions, exploration, and development activities:
| | | Year ended December 31, | |
| | | 2023 | | | 2022 | |
| Acquisition Costs: | | | | | | | | |
| Proved | | $ | 134,895 | | | $ | 1,028,411 | |
| Unproved | | | 720,003 | | | | 1,213,079 | |
| Exploration Costs | | | | | | | | |
| Geological and geophysical | | | — | | | | — | |
| Development costs | | | 31,918,742 | | | | 34,719,791 | |
| Total costs incurred | | $ | 32,773,640 | | | $ | 36,961,281 | |
Oil and Natural Gas Reserves
The reserve estimates presented below were made in accordance with accounting principles generally accepted in the United States of America requirements for disclosures about oil and gas producing activities and Securities and Exchange Commission (“SEC”) rules for oil and gas reporting of reserve estimation and disclosure.
Proved reserves are the estimated quantities of oil, gas, and NGLs which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined, and the price to be used is the average price during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions.
The tables below present a summary of changes in the NRO’s estimated net proved reserves for each of the years ended December 31, 2023, 2022, and 2021. All of NRO’s proved reserves are located in the state of Colorado in the United States of America. NRO engaged CG&A to audit internal engineering estimates of NRO’s total calculated proved reserves volumes and net PV-10 for each year presented. NRO emphasizes that reserve estimates are inherently imprecise and that estimates of new discoveries and undeveloped locations are more imprecise than estimates of established producing oil and gas properties. Accordingly, these estimates are expected to change as future information becomes available.
| | | Oil (Bbl) | | | Gas (Mcf) | | | Liquids (Bbl) | | | BOE | |
| Proved Developed and Undeveloped Reserves | | | | | | | | | | | | | | | | |
| As of December 31, 2021 | | | 9,150,124 | | | | 16,386,179 | | | | 4,126,059 | | | | 16,007,213 | |
| Revisions | | | (1,806,746 | ) | | | 875,476 | | | | (850,846 | ) | | | (2,511,680 | ) |
| Extensions | | | 2,238,184 | | | | 5,752,187 | | | | 1,031,821 | | | | 4,228,703 | |
| Divestiture of reserves | | | (1,705,171 | ) | | | (3,197,920 | ) | | | (785,350 | ) | | | (3,023,508 | ) |
| Acquisition of reserves | | | — | | | | — | | | | — | | | | — | |
| Production | | | (618,787 | ) | | | (919,804 | ) | | | (161,585 | ) | | | (933,673 | ) |
| As of December 31, 2022 | | | 7,257,604 | | | | 18,896,118 | | | | 3,360,099 | | | | 13,767,056 | |
| Revisions | | | 177,709 | | | | 485,626 | | | | (40,027 | ) | | | 218,620 | |
| Extensions | | | 1,992,949 | | | | 4,513,455 | | | | 786,530 | | | | 3,531,722 | |
| Divestiture of reserves | | | (155,373 | ) | | | (286,151 | ) | | | (49,733 | ) | | | (252,798 | ) |
| Acquisition of reserves | | | — | | | | — | | | | — | | | | — | |
| Production | | | (616,616 | ) | | | (887,881 | ) | | | (149,000 | ) | | | (913,596 | ) |
| As of December 31, 2023 | | | 8,656,273 | | | | 22,721,167 | | | | 3,907,869 | | | | 16,351,003 | |
| | | | | | | | | | | | | | | | | |
| Proved developed reserves as of: | | | | | | | | | | | | | | | | |
| December 31, 2021 | | | 3,731,662 | | | | 6,669,807 | | | | 1,182,570 | | | | 6,025,867 | |
| December 31, 2022 | | | 2,599,724 | | | | 6,452,542 | | | | 1,103,821 | | | | 4,778,969 | |
| December 31, 2023 | | | 2,481,059 | | | | 7,689,981 | | | | 1,287,231 | | | | 5,049,954 | |
| | | | | | | | | | | | | | | | | |
| Proved undeveloped reserves as of: | | | | | | | | | | | | | | | | |
| December 31, 2021 | | | 5,418,462 | | | | 9,716,372 | | | | 2,943,489 | | | | 9,981,346 | |
| December 31, 2022 | | | 4,657,880 | | | | 12,443,576 | | | | 2,256,278 | | | | 8,988,087 | |
| December 31, 2023 | | | 6,175,214 | | | | 15,031,186 | | | | 2,620,638 | | | | 11,301,050 | |
During the year ended December 31, 2023, NRO’s total proved positive revisions of 219 Mboe were comprised of an increase of 333 Mboe from improved results from development, an increase of 58 Mboe due to the delayed reversionary interest and increased net volumes as a result of a decrease in commodity prices, and a decrease of 172 Mboe due to accelerated reversionary interests as a result of lower capital costs. NRO’s total proved extensions totaled 3,532 Mboe, comprised of the addition of 3,160 Mboe from nine net (nine gross) proved undeveloped locations and 372 Mboe from one net (one gross) proved developed well. NRO spent $22.1 million in development costs drilling four net (four gross) proved undeveloped locations, representing 1,496 Mboe of proved developed reserves as of December 31, 2023, a decrease of 191 Mboe from their respective proved undeveloped reserves at the beginning of 2023. NRO’s forecast shows all proved undeveloped reserves will be drilled within five years. NRO divested 253 Mboe of proved reserves related to the 2023 NRO Divestiture.
During the year ended December 31, 2022, NRO’s total proved negative revisions of 2,512 Mboe were comprised of 2,541 of negative changes to decline curve estimates based on reservoir engineering analysis and well performance, a decrease of 406 Mboe due to accelerated reversionary interests as a result of higher commodity prices and decreased net volumes, and an increase of 435 Mboe due to delayed reversionary interests and increased net volumes as a result of lower capital costs. NRO’s extensions totaled 4,229 Mboe, comprised of the addition of 3,811 Mboe from 13 net (16 gross) proved undeveloped locations and 418 Mboe from one net (one gross) proved developed well. NRO spent $22.9 million in development costs drilling four net (four gross) proved undeveloped locations, representing 1,568 Mboe of proved developed reserves as of December 31, 2022, a decrease of 280 Mboe from their respective proved undeveloped reserves at the beginning of 2022. NRO’s forecast shows all proved undeveloped reserves will be drilled within five years. NRO divested 3,024 Mboe of proved reserves related to the 2022 NRO Divestiture.
Proved Undeveloped Reserves (“PUDs”)
At December 31, 2023, NRO’s estimated PUD reserves were approximately 11,301 Mboe, an increase of 2,313 Mboe over the reserve estimate at December 31, 2022 of 8,988 Mboe.
| | | Oil (Bbl) | | | Gas (Mcf) | | | Liquids (Bbl) | | | BOE | |
| Proved undeveloped reserves at December 31, 2021 | | | 5,418,465 | | | | 9,716,371 | | | | 2,943,486 | | | | 9,981,346 | |
| Revisions | | | (767,075 | ) | | | 1,143,414 | | | | (533,752 | ) | | | (1,110,258 | ) |
| Extensions | | | 2,044,569 | | | | 5,109,608 | | | | 914,658 | | | | 3,810,828 | |
| Divestiture of reserves | | | (1,061,102 | ) | | | (1,672,018 | ) | | | (506,523 | ) | | | (1,846,295 | ) |
| Acquisition of reserves | | | — | | | | — | | | | — | | | | — | |
| Conversions into proved developed reserves (prior year balance) | | | (976,977 | ) | | | (1,853,798 | ) | | | (561,591 | ) | | | (1,847,534 | ) |
| Proved undeveloped reserves at December 31, 2022 | | | 4,657,880 | | | | 12,443,577 | | | | 2,256,278 | | | | 8,988,088 | |
| Revisions | | | 545,132 | | | | 1,207,503 | | | | 145,810 | | | | 892,193 | |
| Extensions | | | 1,818,434 | | | | 3,932,001 | | | | 686,258 | | | | 3,160,026 | |
| Divestiture of reserves | | | (27,183 | ) | | | (72,494 | ) | | | (13,048 | ) | | | (52,314 | ) |
| Acquisition of reserves | | | — | | | | — | | | | — | | | | — | |
| Conversions into proved developed reserves (prior year balance) | | | (819,049 | ) | | | (2,479,401 | ) | | | (454,660 | ) | | | (1,686,943 | ) |
| Proved undeveloped reserves at December 31, 2023 | | | 6,175,214 | | | | 15,031,186 | | | | 2,620,638 | | | | 11,301,050 | |
During the year ended December 31, 2023, the increase in PUD reserves was primarily attributable to extensions of 3,160 Mboe from nine net (nine gross) PUD locations. NRO’s PUD positive revisions of 892 Mboe were comprised of an increase of 720 Mboe attributable to improved results from development, an increase of 247 Mboe due to the delayed reversionary interest and increased net volumes as a result of a decrease in commodity prices, and a decrease of 75 Mboe due to accelerated reversionary interests as a result of lower capital costs. NRO converted into proved developed reserves 1,687 Mboe related to locations that were successfully drilled and completed. NRO divested 52 Mboe of PUD reserves related to the 2023 NRO Divesture.
At December 31, 2022, NRO’s estimated PUD reserves were approximately 8,988 Mboe, a decrease of 993 Mboe over the reserve estimate at December 31, 2021 of 9,981 Mboe. The decrease was primarily due to divestiture of 1,848 Mboe of PUD reserves related to the 2022 NRO Divestiture and conversion of 1,847 Mboe into proved developed reserves related to locations that were successfully drilled and completed. NRO’s negative revisions of 1,110 Mboe of PUD reserves were comprised of a decrease of 978 Mboe from recent well results for development well spacing patterns, a decrease of 345 Mboe due to the accelerated reversionary interest and decreased net volumes as a result of an increase in commodity prices, and an increase of 213 Mboe due to delayed reversionary interests as a result of higher capital costs. NRO’s extensions of 3,811 Mboe were from 13 net (16 gross) PUD locations.
Revisions represent changes in previous reserves estimates, either upward or downward, resulting from new information normally obtained from development drilling and production history or resulting from a change in economic factors, such as commodity prices, operating costs or development costs.
Oil, natural gas and NGLs reserve engineering is an estimation of accumulations of oil, natural gas and NGLs that cannot be measured exactly. The accuracy of any reserves estimate is a function of the quality of available data and engineering and geological interpretation and judgment. Accordingly, reserves estimates may vary from the quantities of oil, natural gas and NGLs that are ultimately recovered.
Capitalized Costs
The following table sets forth the capitalized costs relating to oil and gas properties and accumulated depletion:
| | | Year ended December 31, | |
| | | 2023 | | | 2022 | |
| Proved oil and gas properties | | $ | 137,855,719 | | | $ | 113,415,744 | |
| Unproved oil and gas properties | | | 1,690,690 | | | | 1,068,954 | |
| Accumulated depletion | | | (41,010,449 | ) | | | (25,691,574 | ) |
| Net capitalized costs | | $ | 98,535,960 | | | $ | 88,793,124 | |
Standardized Measure of Discounted Future Net Cash Flows
NRO computes a standardized measure of discounted future net cash flows and changes therein relating to estimated proved reserves in accordance with authoritative accounting guidance. Future cash inflows and production and development costs are determined by applying prices and costs, including transportation, quality, and basis differentials, to the year-end estimated future reserve quantities. Estimated future income taxes are computed using the current statutory income tax rates, including consideration for estimated future statutory depletion. The resulting future net cash flows are reduced to present value amounts by applying a 10 percent annual discount factor.
Future operating costs and production taxes are determined based on estimates of expenditures to be incurred in developing and producing the estimated proved reserves at the end of the period using year end costs and assuming continuation of existing economic conditions, plus estimated abandonment costs.
The assumptions used to compute the Standardized Measure of discounted future net cash flows are those prescribed by the Financial Accounting Standards Board and the SEC. These assumptions do not necessarily reflect NRO’s expectations of actual revenues to be derived from those reserves, nor their present value amount. The limitations inherent in the reserve quantity estimation process, as discussed previously, are equally applicable to the standardized measure of discounted future net cash flows computations since these reserve quantity estimates are the basis for the valuation process. The following prices used in the calculation of proved reserve estimates reflect the unweighted arithmetic average of the first-day-of-the-month price of each month within the trailing 12-month period in accordance with SEC rules. We then adjust these prices to reflect transportation, quality and location differentials over the period in estimating our net proved reserves.
| | | Year ended December 31, | |
| | | 2023 | | | 2022 | |
| Oil ($/Bbl) | | $ | 78.22 | | | $ | 93.67 | |
| Gas ($/Mmbtu) | | $ | 2.64 | | | $ | 6.36 | |
The Standardized Measure of discounted future net cash flows from NRO’s proved oil and gas reserves is presented in the following table:
| | | Year ended December 31, | |
| | | 2023 | | | 2022 | |
| Future cash inflows | | $ | 797,665,069 | | | $ | 883,016,626 | |
| Future production costs and taxes | | | (304,141,326 | ) | | | (293,548,055 | ) |
| Future development costs | | | (170,282,285 | ) | | | (147,621,778 | ) |
| Future income tax expense | | | — | | | | — | |
| Future net cash flows | | | 323,241,458 | | | | 441,846,793 | |
| 10% annual discount for estimated timing of cash flows | | | (149,312,372 | ) | | | (197,175,725 | ) |
| Standardized Measure of discounted future net cash flows | | $ | 173,929,086 | | | $ | 244,671,068 | |
The following are the principal sources of changes in the standardized measure of discounted future net cash flows from NRO’s proved oil and gas reserves:
| | | Year ended December 31, | |
| | | 2023 | | | 2022 | |
| Balance, beginning of year | | $ | 244,671,068 | | | $ | 259,924,928 | |
| Net change in prices and production costs | | | (98,531,959 | ) | | | 66,158,782 | |
| Net change in future development costs | | | 3,286,634 | | | | (18,682,942 | ) |
| Oil and gas net revenue | | | (39,144,165 | ) | | | (57,149,450 | ) |
| Extensions | | | 31,061,825 | | | | 52,216,906 | |
| Acquisition of reserves | | | — | | | | — | |
| Divestiture of reserves | | | (8,286,790 | ) | | | (48,657,637 | ) |
| Revisions of previous quantity estimates | | | 3,822,640 | | | | (49,945,233 | ) |
| Previously estimated development costs incurred | | | 21,453,129 | | | | 15,239,276 | |
| Net change in taxes | | | — | | | | — | |
| Accretion of discount | | | 24,467,107 | | | | 25,992,493 | |
| Changes in timing and other | | | (8,870,403 | ) | | | (426,055 | ) |
| Balance, end of year | | $ | 173,929,086 | | | $ | 244,671,068 | |
Internal Controls and Qualifications of Technical Persons
In accordance with the Reserve Standards and guidelines established by the SEC, CG&A estimated 100% of NRO’s proved reserve information as of December 31, 2023. The technical persons responsible for preparing the reserves estimates presented herein meet the requirements regarding qualifications, independence, objectivity and confidentiality set forth in the Reserve Standards.
NRO maintains an internal staff of petroleum engineers and geoscience professionals who work closely with its independent reserve engineers to ensure the integrity, accuracy and timeliness of the data used to calculate its proved reserves relating to its assets. NRO’s internal technical team members met with independent reserve engineers periodically during the period covered by the reserve report to discuss the assumptions and methods used in the proved reserve estimation process. NRO provides historical information to the independent reserve engineers for its properties such as ownership interest, oil and natural gas production, well data, commodity prices and operating and development costs.
The preparation of NRO’s proved reserve estimates is completed in accordance with NRO’s internal control procedures. These procedures, which are intended to ensure reliability of reserve estimations, include the following:
| | ● | review and verification of historical production data, working interest, net revenue interest, lease operating statements, capital costs, severance and ad valorem taxes, which data is based on actual production as reported by NRO; |
| | | |
| | ● | verification of property ownership by NRO’s land department; |
| | | |
| | ● | preparation of reserve estimates by NRO’s Co-President; |
| | | |
| | ● | review by NRO’s Co-President of all of NRO’s reported proved reserves, including the review of all significant reserve changes and all new proved undeveloped reserves additions; and |
| | | |
| | ● | direct reporting responsibilities and final approval by NRO’s Co-President to NRO’s Management Committee. |
Andrew Haney, Co-President, is the technical person primarily responsible for overseeing the preparation of NRO’s reserves estimates. He has over 20 years of experience in the oil and gas industry with experience in reservoir engineering, production operations, drilling and planning for multiple public and private companies. He has a Bachelor of Science degree in Petroleum Engineering from the Colorado School of Mines and a Master of Science in Global Energy Management from the University of Colorado. He is a member of the Society of Petroleum Engineers.
Drilling Activity
The following table sets forth the exploratory and development wells completed (operated and non-operated) during the years ended December 31, 2023 and 2022:
| | | Year Ended December 31 | |
| | | 2023 | | | 2022 | |
| | | Gross | | | Net | | | Gross | | | Net | |
| Exploratory | | | | | | | | | | | | | | | | |
| Productive Wells | | | — | | | | — | | | | — | | | | — | |
| Dry Wells | | | — | | | | — | | | | — | | | | — | |
| Total Exploratory Wells | | | — | | | | — | | | | — | | | | — | |
| Development | | | | | | | | | | | | | | | | |
| Productive Wells | | | 5 | | | | 5 | | | | 5 | | | | 5 | |
| Dry Wells | | | — | | | | — | | | | — | | | | — | |
| Total Development Wells | | | 5 | | | | 5 | | | | 5 | | | | 5 | |
| Total | | | 5 | | | | 5 | | | | 5 | | | | 5 | |
At December 31, 2023, NRO did not have any wells that were in the process of being drilled, completed, awaiting completion, or any other related material activities.
As a result of the NRO Acquisition, NRO did not drill and complete any wells during the nine months ended September 30, 2024.
Production and Cost History
The following tables set forth information regarding net production of oil, natural gas and NGLs and certain price and cost information for each of the periods indicated. The information set forth below related to NRO consists of the historical results for the nine months ended September 30, 2024 and 2023 and years ended December 31, 2023 and 2022:
| | | Nine Months Ended September 30, | | | Year Ended December 31, | |
| | | 2024 | | | 2023 | | | 2023 | | | 2022 | |
| Oil: | | | | | | | | | | | | | | | | |
| Total production (Mbbls) | | | 398 | | | | 439 | | | | 617 | | | | 619 | |
| Average sales price ($ per Bbl), including derivatives | | $ | 75.50 | | | $ | 73.11 | | | $ | 73.46 | | | $ | 61.14 | |
| Average sales price ($ per Bbl), excluding derivatives | | $ | 74.94 | | | $ | 74.69 | | | $ | 75.06 | | | $ | 93.29 | |
| Natural Gas: | | | | | | | | | | | | | | | | |
| Total production (MMcf) | | | 794 | | | | 585 | | | | 888 | | | | 920 | |
| Average sales price ($ per Mcf), including derivatives | | $ | 0.43 | | | $ | 0.73 | | | $ | 0.75 | | | $ | 2.30 | |
| Average sales price ($ per Mcf), excluding derivatives | | $ | 0.43 | | | $ | 0.89 | | | $ | 0.79 | | | $ | 4.32 | |
| Natural Gas Liquids: | | | | | | | | | | | | | | | | |
| Total production (Mbbls) | | | 102 | | | | 105 | | | | 149 | | | | 162 | |
| Average sales price ($ per Bbl), including derivatives | | $ | 6.05 | | | $ | 8.47 | | | $ | 7.77 | | | $ | 26.78 | |
| Average sales price ($ per Bbl), excluding derivatives | | $ | 6.05 | | | $ | 8.47 | | | $ | 7.77 | | | $ | 26.78 | |
| Oil Equivalents: | | | | | | | | | | | | | | | | |
| Total production (MBoe) | | | 632 | | | | 642 | | | | 914 | | | | 934 | |
| Average daily production (Boe/d) | | | 2,307 | | | | 2,350 | | | | 2,504 | | | | 2,559 | |
| Average production costs ($ per Boe)(1)(2) | | $ | 11.65 | | | $ | 9.17 | | | $ | 9.29 | | | $ | 8.33 | |
| (1) | Excludes ad valorem and severance taxes |
| | |
| (2) | Represents lease operating expense and gathering, transportation, and processing per Boe using total production volumes. |
Wells
The following table sets forth the number wells in which NRO owned a working interest, all of which are operated as of December 31, 2023:
| | | Total | |
| | | Gross | | | Net | |
| DJ Basin | | | 26 | | | | 25 | |
Developed and Undeveloped Acreage
The following table sets forth NRO’s leasehold acreage as of December 31, 2023.
| | | Developed Acres | | | Undeveloped Acres | | | Total Acres | |
| | | Gross | | | Net | | | Gross | | | Net | | | Gross | | | Net | |
| DJ Basin | | | 5,035 | | | | 4,707 | | | | 901 | | | | 819 | | | | 5,938 | | | | 5,525 | |
All of the leases comprising the undeveloped acreage set forth in the table above will expire at the end of their primary terms unless an extension provision within the lease is executed or production has been established, in which event the lease will remain in effect until the cessation of production. The following table sets forth, as of December 31, 2023, the extension provisions of the undeveloped acres subject to leases summarized in the above table of developed and undeveloped acreage.
| | | 2024 | | | 2025 | | | 2026 | |
| | | Gross | | | Net | | | Gross | | | Net | | | Gross | | | Net | |
| Extension Acres | | | 234 | | | | 234 | | | | — | | | | — | | | | 3 | | | | 3 | |
All of the leases comprising the undeveloped acreage set forth in the acreage tables above will expire at the end of their respective primary terms unless production from the leasehold acreage has been established prior to such date, in which event the lease will remain in effect until the cessation of production. The following table sets forth, as of March 31, 2024, the expiration periods of the undeveloped acres that are subject to leases summarized in the above acreage tables.
| | | 2024 | | | 2025 | | | 2026 | |
| | | Gross | | | Net | | | Gross | | | Net | | | Gross | | | Net | |
| Expiration | | | 180 | | | | 180 | | | | 80 | | | | 80 | | | | 373 | | | | 304 | |
Operations
General
NRO is the operator of substantially all of its acreage. As operator, NRO obtains regulatory authorizations, designs and manages the development of a well and supervises operation and maintenance activities on a day-to-day basis. NRO does not own drilling rigs or the majority of the other oil field service equipment used for drilling or maintaining wells on the properties it operates. Independent contractors engaged by NRO provide a majority of the equipment and personnel associated with these activities. NRO utilizes the services of drilling, production and reservoir engineers and geologists and other specialists who work to improve production rates, increase reserves and lower the cost of operating NRO’s oil and natural gas properties.
Marketing
NRO markets all of the oil, natural gas and NGL production from its operated properties. For the nine months ended September 30, 2024, NRO sold all of its oil, natural gas and NGL production to four purchasers, one of which accounted for 89% of NRO’s sales and one customer accounted for approximately 94% of accrued oil and gas sales. For the nine months ended September 30, 2023, NRO’s largest customers accounted for 90% of NRO’s sales and one customer accounted for approximately 93% of accrued oil and gas sales.
As of and for the year ended December 31, 2023, NRO’s largest customer generated approximately 90% of sales, and one customer accounted for approximately 95% of accrued oil and gas sales. As of and for the year ended December 31, 2022, NRO’s two largest customers generated approximately 82% and 15% of sales, and one customer accounted for approximately 88% of accrued oil and gas sales. The loss of any single purchaser could materially and adversely affect NRO’s revenues in the short-term; however, NRO believes that the loss of any of its purchasers would not have a long-term material adverse effect on its results of operations as oil, natural gas and NGLs are fungible products with well-established markets and numerous purchasers.
The majority of NRO’s production is party to crude oil purchase contracts, pursuant to which the counterparty is required to receive and purchase all crude oil produced from wells operated by NRO delivered to a terminal located in Weld County. NRO predominantly utilizes trucking to deliver its crude oil to the purchasers.
NRO is a party to various gas gathering agreements pursuant to which it has dedicated acreage, which the counterparty is required to receive and purchase all natural gas produced from wells operated by NRO located within the dedicated area through the term of the contracts. In exchange for NRO’s land dedication, NRO receives certain gathering and delivery rights.
NRO is party to produced water agreements where it has dedicated its acreage to deliver produced water to certain water disposal facilities located throughout Weld County.
Title to Properties
NRO has obtained title opinions on substantially all of its producing properties and believes that it utilizes methods consistent with practices customary in the oil and gas industry and that its practices are adequately designed to enable it to acquire satisfactory title to its producing properties. Prior to completing an acquisition of producing oil and gas leases, NRO performs title reviews on the most significant leases and, depending on the materiality of the properties, NRO may obtain a title opinion or review previously obtained title opinions. NRO’s oil, natural gas and NGL producing properties are subject to customary royalty and other interests, liens for current taxes, liens under its existing credit facility and other burdens, none of which materially interfere with NRO’s use of its properties.
Employees
NRO does not have, and never has had, any employees. NRO’s key personnel are employees of an affiliated management company to which NRO pays a monthly service fee. NRO also contracts for the services of independent consultants involved in field operations, land, regulatory, accounting, financial and other disciplines as needed.
Offices
Since its inception, NRO has leased, or subleased, sufficient office space to support its business operations. Since October 1, 2023, NRO’s offices have been located at 3773 Cherry Creek North Drive, Suite 670, Denver, Colorado 80209.
Legal Proceedings
NRO is not a party to any lawsuits and, since its inception, has not been a party to any material lawsuits. NRO cannot predict whether it will in the future be subject to lawsuits in the normal course of its business. NRO’s management, however, believes that there are no facts surrounding its operations that would support any such lawsuits or lead to damages that could have a material adverse effect on its operations or its financial condition.
