Filing summary
Identity and period: The supplied filing is Black Ridge Oil & Gas, Inc.’s Form 10-K for the fiscal year ended December 31, 2014, filed March 30, 2015. It does not identify Sow Good Inc.; the filing says the company’s stock traded on OTCQB under “ANFC.” The requested “2014 Q4” period is not a separate quarterly report: this is an annual filing with full-year 2014 results and a December 31 year-end.
Business context and reporting period
Black Ridge was a non-operating oil and natural gas exploration and production company focused on the Bakken and Three Forks formations in North Dakota and Montana. It relied on third-party operators to drill, complete, and market production. At year-end it reported approximately 10,000 net acres, 7.88 net producing wells, average fourth-quarter production of 1,190 Boe per day, and proved reserves of 5.36 million Boe.
Financial and operating metrics
| Metric | 2014 | 2013 |
|---|---|---|
| Oil and gas sales | $21.10 million | $9.28 million |
| Total revenues, including derivative gains/losses | $29.41 million | $9.12 million |
| Net operating income | $12.20 million | $0.92 million |
| Net income (loss) | $4.35 million | $(0.40) million |
| Adjusted EBITDA (non-GAAP) | $14.39 million | $5.87 million |
| Adjusted net income (loss) (non-GAAP) | $(0.56) million | $(0.50) million |
| Cash from operating activities | $8.94 million | $6.09 million |
| Cash used in investing activities | $(29.14) million | $(32.34) million |
- Production rose 168% to 291,780 Boe. Oil and gas sales increased 127%, partly offset by lower realized prices: realized oil price before settled derivatives was $78.64 per barrel versus $89.58; realized price per Boe, net of settled derivatives, was $74.08 versus $85.75.
- Net income included a $7.79 million unrealized mark-to-market derivative gain and $0.51 million of realized derivative gains. The unrealized gain was noncash; excluding the mark-to-market effect, adjusted net income was a loss.
- Operating expenses were $17.21 million, including $9.36 million of depletion. Production cost declined to $9.27 per Boe from $10.53, while general and administrative expense increased 26% to $2.89 million.
- At December 31, cash was $94,682; current assets were $9.45 million, current liabilities $10.35 million, and working capital was negative $0.90 million. Accounts receivable was $5.74 million.
- Debt principal was $53.91 million, including $22.6 million under the senior facility and $30.0 million under the subordinated facility, plus $1.31 million of accrued PIK interest. Balance-sheet debt net of discounts was $51.83 million. Year-end borrowing-base availability was reported as $12.4 million.
- Capital expenditures for oil and gas acquisition and development were approximately $32.2 million. The company reported $16.5 million of outstanding AFE commitments at year-end.
Material changes versus 2013
- Production growth, more producing wells, and development activity drove higher sales and an 18% increase in proved reserves, from 4.54 million to 5.36 million Boe. The company completed or participated in 94 gross (3.01 net) wells in 2014.
- Oil and gas sales grew substantially, but average realized oil and gas prices declined. Interest expense rose to $5.29 million from $2.38 million as borrowings increased; total debt principal and accrued PIK interest rose from $33.20 million to $53.91 million.
- Operating cash flow increased, while investing cash outflows remained high. Cash declined from $1.15 million to $94,682.
- Proved undeveloped reserves were 3.33 million Boe, down 5% year over year; the filing attributes negative revisions partly to wells becoming uneconomic at lower oil prices. No full-cost ceiling impairment was recorded in 2014 or 2013.
Outlook, risks, contingencies, and unusual items
- Management said 2015 revenues were not expected to exceed investment in well development and operating costs, but believed the credit facilities would fund planned property acquisition and development. The filing gives no specific production, revenue, earnings, or capital-spending guidance.
- On March 30, 2015, after year-end, lenders reduced the senior borrowing base from $35 million to $34 million, extended its termination date to January 15, 2017, and waived specified leverage and collateral-coverage covenants for the first quarter of 2015. Amendments also revised subsequent covenant limits. These changes underscore financing and covenant risk.
- The subordinated facility carries a cash interest rate of at least 10% plus 4% PIK interest; both facilities are secured by substantially all company assets. A 1 percentage-point increase in interest rates was estimated to add about $545,000 in annual interest expense.
- The company had oil swaps covering 249,000 barrels at a weighted-average price of about $88.97 per barrel, plus costless collars. Hedging may support prices but limits upside and can create liquidity or counterparty exposure.
- Management warned that lower commodity prices could reduce borrowing capacity and reserve values and could trigger a noncash ceiling-test write-down in 2015. It estimated that year-end PV-10 could be about 52% lower using more recent market pricing assumptions. SEC-price PV-10 was $100.3 million; the standardized measure of discounted future net cash flows was $85.1 million.
- Other material risks include dependence on third-party operators, limited liquidity and access to capital, concentrated exposure to the Williston Basin, lease expirations, transportation constraints, environmental and hydraulic-fracturing regulation, and potential dilution. Approximately 62% of proved reserves were undeveloped.
- The filing reports $16.5 million of AFE commitments and a title dispute involving a North Dakota riverbed lease. The company had not recognized revenue or capitalized AFE costs for the affected well; the filing estimates that recognition would have added approximately $230,000 to 2014 sales. Management reported no material litigation and no material off-balance-sheet arrangements.
- The board and shareholders had approved a potential reverse split of up to 1-for-10, but the board had not made it effective as of filing. The company reported no dividends and no material change in internal control; management deemed disclosure controls and internal control over financial reporting effective. The auditor gave an unqualified opinion on the financial statements but did not attest to internal controls.
Important facts for investors to verify
- Confirm the issuer: this filing is for Black Ridge Oil & Gas, Inc., not Sow Good Inc.; verify the intended company and filing.
- Review current borrowing-base availability, covenant compliance, waiver terms, debt service, and the effect of the March 2015 amendments.
- Assess cash generation excluding unrealized derivative gains, hedge coverage and settlement exposure, and sensitivity to commodity prices.
- Verify reserve assumptions, the proportion and development schedule of undeveloped reserves, potential lease expirations, and ceiling-test impairment exposure.
- Evaluate the company’s funding needs against its low cash balance, AFE commitments, and stated expectation that 2015 revenue would not cover investment and operating costs.