Document and Entity Information
Document and Entity Information - shares | 3 Months Ended | |
Dec. 31, 2018 | Feb. 08, 2019 | |
Document and Entity Information | ||
Entity Registrant Name | BARNWELL INDUSTRIES INC | |
Entity Central Index Key | 10,048 | |
Document Type | 10-Q | |
Document Period End Date | Dec. 31, 2018 | |
Amendment Flag | false | |
Current Fiscal Year End Date | --09-30 | |
Entity Current Reporting Status | Yes | |
Entity Filer Category | Smaller Reporting Company | |
Entity Common Stock, Shares Outstanding | 8,277,160 | |
Document Fiscal Year Focus | 2,019 | |
Document Fiscal Period Focus | Q1 |
CONDENSED CONSOLIDATED BALANCE
CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands | Dec. 31, 2018 | Sep. 30, 2018 |
Current assets: | ||
Cash and cash equivalents | $ 6,098 | $ 5,965 |
Certificates of deposit | 0 | 741 |
Accounts and other receivables, net of allowance for doubtful accounts of: $40,000 at December 31, 2018; $42,000 at September 30, 2018 | 1,465 | 1,965 |
Income taxes receivable | 1,503 | 2,461 |
Other current assets | 1,765 | 950 |
Total current assets | 10,831 | 12,082 |
Income taxes receivable, net of current portion | 460 | 429 |
Asset for retirement benefits | 865 | 848 |
Investments | 1,177 | 1,608 |
Property and equipment | 70,241 | 73,010 |
Accumulated depletion, depreciation, and amortization | (56,896) | (56,599) |
Property and equipment, net | 13,345 | 16,411 |
Total assets | 26,678 | 31,378 |
Current liabilities: | ||
Accounts payable | 1,604 | 1,191 |
Accrued capital expenditures | 156 | 232 |
Accrued compensation | 495 | 568 |
Accrued operating and other expenses | 957 | 1,140 |
Current portion of asset retirement obligation | 554 | 444 |
Other current liabilities | 452 | 54 |
Total current liabilities | 4,218 | 3,629 |
Deferred rent | 129 | 107 |
Liability for retirement benefits | 4,463 | 4,410 |
Asset retirement obligation | 6,446 | 6,678 |
Deferred income tax liabilities | 239 | 315 |
Total liabilities | 15,495 | 15,139 |
Commitments and contingencies | ||
Equity: | ||
Common stock, par value $0.50 per share; authorized, 20,000,000 shares: 8,445,060 issued at December 31, 2018 and September 30, 2018 | 4,223 | 4,223 |
Additional paid-in capital | 1,350 | 1,350 |
Retained earnings | 8,673 | 13,253 |
Accumulated other comprehensive loss, net | (910) | (514) |
Treasury stock, at cost: 167,900 shares at December 31, 2018 and September 30, 2018 | (2,286) | (2,286) |
Total stockholders' equity | 11,050 | 16,026 |
Non-controlling interests | 133 | 213 |
Total equity | 11,183 | 16,239 |
Total liabilities and equity | $ 26,678 | $ 31,378 |
CONDENSED CONSOLIDATED BALANC_2
CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands | Dec. 31, 2018 | Sep. 30, 2018 |
Statement of Financial Position [Abstract] | ||
Accounts receivable, allowance for doubtful accounts | $ 40 | $ 42 |
Common stock, par value (in dollars per share) | $ 0.50 | $ 0.50 |
Common stock, authorized shares | 20,000,000 | 20,000,000 |
Common stock, issued shares | 8,445,060 | 8,445,060 |
Treasury stock, shares | 167,900 | 167,900 |
CONDENSED CONSOLIDATED STATEMEN
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands | 3 Months Ended | |
Dec. 31, 2018 | Dec. 31, 2017 | |
Revenues: | ||
Revenues | $ 2,595 | $ 1,856 |
Costs and expenses: | ||
Oil and natural gas operating | 1,337 | 658 |
Contract drilling operating | 1,316 | 821 |
General and administrative | 1,548 | 1,481 |
Depletion, depreciation, and amortization | 819 | 280 |
Impairment of assets | 2,170 | 0 |
Interest expense | 4 | 0 |
Total costs and expenses | 7,194 | 3,240 |
Loss before equity in loss of affiliates and income taxes | (4,599) | (1,384) |
Equity in loss of affiliates | (79) | (153) |
Loss before income taxes | (4,678) | (1,537) |
Income tax benefit | (105) | (503) |
Net loss | (4,573) | (1,034) |
Less: Net earnings (loss) attributable to non-controlling interests | 27 | (17) |
Net loss attributable to Barnwell Industries, Inc. | $ (4,600) | $ (1,017) |
Basic and diluted net loss per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share) | $ (0.56) | $ (0.12) |
Weighted-average number of common shares outstanding: | ||
Basic and diluted (in shares) | 8,277 | 8,277 |
Oil and natural gas | ||
Revenues: | ||
Revenues | $ 1,232 | $ 953 |
Costs and expenses: | ||
Depletion, depreciation, and amortization | 749 | 199 |
Impairment of assets | 2,170 | 0 |
Contract drilling | ||
Revenues: | ||
Revenues | 1,163 | 842 |
Costs and expenses: | ||
Depletion, depreciation, and amortization | 57 | 61 |
Land investment | ||
Revenues: | ||
Revenues | 165 | 0 |
Gas processing and other | ||
Revenues: | ||
Revenues | 35 | 61 |
Costs and expenses: | ||
Depletion, depreciation, and amortization | $ 13 | $ 20 |
CONDENSED CONSOLIDATED STATEM_2
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands | 3 Months Ended | |
Dec. 31, 2018 | Dec. 31, 2017 | |
Statement of Comprehensive Income [Abstract] | ||
Net loss | $ (4,573) | $ (1,034) |
Other comprehensive (loss) income: | ||
Foreign currency translation adjustments, net of taxes of $0 | (413) | (6) |
Retirement plans - amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | 17 | 24 |
Total other comprehensive (loss) income | (396) | 18 |
Total comprehensive loss | (4,969) | (1,016) |
Less: Comprehensive income (loss) attributable to non-controlling interests | 27 | (17) |
Comprehensive loss attributable to Barnwell Industries, Inc. | $ (4,996) | $ (999) |
CONDENSED CONSOLIDATED STATEM_3
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Parenthetical) - USD ($) $ in Thousands | 3 Months Ended | |
Dec. 31, 2018 | Dec. 31, 2017 | |
Statement of Comprehensive Income [Abstract] | ||
Foreign currency translation adjustments, taxes | $ 0 | $ 0 |
Amortization of accumulated other comprehensive loss into net periodic benefit cost, taxes | $ 0 | $ 0 |
CONDENSED CONSOLIDATED STATEM_4
CONDENSED CONSOLIDATED STATEMENTS OF EQUITY - USD ($) $ in Thousands | Total | Common Stock | Additional Paid-In Capital | Retained Earnings | Accumulated Other Comprehensive Loss | Treasury Stock | Non-controlling Interests |
Balance, beginning of period (in shares) at Sep. 30, 2017 | 8,277,160 | ||||||
Balance, beginning of period at Sep. 30, 2017 | $ 18,183 | $ 4,223 | $ 1,350 | $ 15,023 | $ (1,058) | $ (2,286) | $ 931 |
Increase (Decrease) in Stockholders' Equity | |||||||
Distributions to non-controlling interests | (506) | (506) | |||||
Net (loss) earnings | (1,034) | (1,017) | (17) | ||||
Share-based compensation | 1 | 1 | |||||
Foreign currency translation adjustments, net of taxes of $0 | (6) | (6) | |||||
Retirement plans - amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | 24 | 24 | |||||
Balance, end of period (in shares) at Dec. 31, 2017 | 8,277,160 | ||||||
Balance, end of period at Dec. 31, 2017 | 16,662 | $ 4,223 | 1,351 | 14,006 | (1,040) | (2,286) | 408 |
Balance, beginning of period (in shares) at Sep. 30, 2018 | 8,277,160 | ||||||
Balance, beginning of period at Sep. 30, 2018 | 16,239 | $ 4,223 | 1,350 | 13,253 | (514) | (2,286) | 213 |
Increase (Decrease) in Stockholders' Equity | |||||||
Cumulative impact from the adoption of ASU No. 2014-09 | 20 | 20 | |||||
Distributions to non-controlling interests | (107) | (107) | |||||
Net (loss) earnings | (4,573) | (4,600) | 27 | ||||
Foreign currency translation adjustments, net of taxes of $0 | (413) | (413) | |||||
Retirement plans - amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | 17 | 17 | |||||
Balance, end of period (in shares) at Dec. 31, 2018 | 8,277,160 | ||||||
Balance, end of period at Dec. 31, 2018 | $ 11,183 | $ 4,223 | $ 1,350 | $ 8,673 | $ (910) | $ (2,286) | $ 133 |
CONDENSED CONSOLIDATED STATEM_5
CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Parenthetical) - USD ($) $ in Thousands | 3 Months Ended | |
Dec. 31, 2018 | Dec. 31, 2017 | |
Statement of Stockholders' Equity [Abstract] | ||
Foreign currency translation adjustments, taxes | $ 0 | $ 0 |
Amortization of accumulated other comprehensive loss into net periodic benefit cost, taxes | $ 0 | $ 0 |
CONDENSED CONSOLIDATED STATEM_6
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands | 3 Months Ended | |
Dec. 31, 2018 | Dec. 31, 2017 | |
Cash flows from operating activities: | ||
Net loss | $ (4,573) | $ (1,034) |
Adjustments to reconcile net earnings (loss) to net cash used in operating activities: | ||
Equity in loss of affiliates | 79 | 153 |
Depletion, depreciation, and amortization | 819 | 280 |
Impairment of assets | 2,170 | 0 |
Retirement benefits expense | 54 | 59 |
Accretion of asset retirement obligation | 150 | 96 |
Income tax receivable, noncurrent | (31) | (460) |
Deferred rent liability | 22 | 22 |
Deferred income tax (benefit) expense | (72) | 70 |
Asset retirement obligation payments | (33) | (436) |
Share-based compensation (benefit) expense | (24) | 17 |
Retirement plan contributions and payments | (2) | (5) |
Sale of interest in leasehold land, net of fees paid | (124) | 0 |
Increase (decrease) from changes in current assets and liabilities | 567 | (549) |
Net cash used in operating activities | (998) | (1,787) |
Cash flows from investing activities: | ||
Purchases of certificates of deposit | 0 | (992) |
Proceeds from the maturity of certificates of deposit | 741 | 248 |
Net proceeds (fees paid on) from sale of interest in leasehold land | 124 | (343) |
Distribution from equity investees in excess of earnings | 352 | 0 |
Proceeds from sale of oil and natural gas assets | 633 | 35 |
Payments to acquire oil and natural gas properties | (355) | 0 |
Capital expenditures - oil and natural gas | (108) | (147) |
Capital expenditures - all other | (96) | (18) |
Net cash provided by (used in) investing activities | 1,291 | (1,217) |
Cash flows from financing activities: | ||
Distributions to non-controlling interests | (107) | (506) |
Net cash used in financing activities | (107) | (506) |
Effect of exchange rate changes on cash and cash equivalents | (53) | (7) |
Net increase (decrease) in cash and cash equivalents | 133 | (3,517) |
Cash and cash equivalents at beginning of period | 5,965 | 16,281 |
Cash and cash equivalents at end of period | $ 6,098 | $ 12,764 |
SUMMARY OF SIGNIFICANT ACCOUNTI
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES | 3 Months Ended |
Dec. 31, 2018 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES | SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Principles of Consolidation The condensed consolidated financial statements include the accounts of Barnwell Industries, Inc. and all majority-owned subsidiaries (collectively referred to herein as “Barnwell,” “we,” “our,” “us,” or the “Company”), including a 77.6% -owned land investment general partnership (Kaupulehu Developments), a 75% -owned land investment partnership (KD Kona 2013 LLLP) and an 80% -owned joint venture (Kaupulehu 2007, LLLP). All significant intercompany accounts and transactions have been eliminated. Undivided interests in oil and natural gas exploration and production joint ventures are consolidated on a proportionate basis. Barnwell’s investments in both unconsolidated entities in which a significant, but less than controlling, interest is held and in variable interest entities in which the Company is not deemed to be the primary beneficiary are accounted for by the equity method. Unless otherwise indicated, all references to “dollars” in this Form 10-Q are to U.S. dollars. Unaudited Interim Financial Information The accompanying unaudited condensed consolidated financial statements and notes have been prepared by Barnwell in accordance with the rules and regulations of the United States (“U.S.”) Securities and Exchange Commission. Accordingly, certain information and footnote disclosures normally included in the annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted pursuant to those rules and regulations, although the Company believes that the disclosures made are adequate to make the information not misleading. These condensed consolidated financial statements and notes should be read in conjunction with the consolidated financial statements and notes thereto included in Barnwell’s September 30, 2018 Annual Report on Form 10-K. The Condensed Consolidated Balance Sheet as of September 30, 2018 has been derived from audited consolidated financial statements. In the opinion of management, all adjustments (which include only normal recurring adjustments) necessary to present fairly the financial position at December 31, 2018 , results of operations, comprehensive loss, equity and cash flows for the three months ended December 31, 2018 and 2017 , have been made. The results of operations for the period ended December 31, 2018 are not necessarily indicative of the operating results for the full year. Use of Estimates in the Preparation of Condensed Consolidated Financial Statements The preparation of the condensed consolidated financial statements in conformity with U.S. GAAP requires management of Barnwell to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Actual results could differ significantly from those estimates. Significant assumptions are required in the valuation of deferred tax assets, asset retirement obligations, share-based payment arrangements, obligations for retirement plans, contract drilling estimated costs to complete, proved oil and natural gas reserves, and the carrying value of other assets, and such assumptions may impact the amount at which such items are recorded. Revenue Recognition On October 1, 2018, the Company adopted Accounting Standards Updates (“ASU”) No. 2014-09, “Revenue from Contracts with Customers” (“Topic 606”) using the modified retrospective method applied to all contracts. Results for reporting periods beginning October 1, 2018 are presented under Topic 606, while prior period amounts are not adjusted and continue to be reported under the accounting standards in effect for the prior period. The Company recorded an adjustment to retained earnings on October 1, 2018 due to the cumulative impact of adopting Topic 606. See Note 7 “Revenue from Contracts with Customers” for the required disclosures related to the impact of adopting this standard and a discussion of the Company’s updated policies related to revenue recognition discussed below. Barnwell operates in and derives revenue from the following three principal business segments: • Oil and Natural Gas Segment - Barnwell engages in oil and natural gas development, production, acquisitions and sales in Canada. • Land Investment Segment - Barnwell invests in land interests in Hawaii. • Contract Drilling Segment - Barnwell provides well drilling services and water pumping system installation and repairs in Hawaii. Oil and Natural Gas - Barnwell’s investments in oil and natural gas properties are located in Alberta, Canada. These property interests are principally held under governmental leases or licenses. Barnwell sells the large majority of its oil, natural gas and natural gas liquids production under short-term contracts between itself and marketers based on prices indexed to market prices and recognizes revenue at a point in time when the oil, natural gas and natural gas liquids are delivered, as this is where Barnwell’s performance obligation is satisfied and title has passed to the customer. Under Topic 606, there were no changes to revenue recognition for the Oil and Natural Gas segment. Land Investment - Barnwell is entitled to receive contingent residual payments from the entities that previously purchased Barnwell’s land investment interests under contracts entered into in prior years. The residual payments under those contracts become due when the entities sell lots and/or residential units in the areas that were previously sold under the aforementioned contracts or when a preferred payment threshold is achieved. Prior to the adoption of Topic 606, the payments received by Barnwell were deemed contingent revenues under the full accrual method and were recognized as revenues when payment is assured, which was generally when a lot sale occurred or the preferred payments were made. The adoption of Topic 606 did not fundamentally change the way Barnwell recognizes these contingent residual revenue payments due primarily to the variable consideration constraint provision of Topic 606, whereby the constraint is removed only when it is probable that a significant reversal in the amount of cumulative revenue recognized will not occur. As such, there were no significant changes to revenue recognition for the Land Investment segment under Topic 606. Contract Drilling - Through fixed price contracts which are normally less than twelve months in duration, Barnwell drills water and water monitoring wells and installs and repairs water pumping systems in Hawaii. Under the Topic 606 requirements, Barnwell recognizes revenue from well drilling or the installation of pumps over time based on total costs incurred on the projects relative to the total expected costs to satisfy the performance obligation as management believes this is an accurate representation of the percentage of completion as control is continuously transferred to the customer. Uninstalled materials, which typically consists of well casing or pumps, are excluded in the costs-to-costs calculation for the duration of the contract as including these costs would result in a distortion of progress towards satisfaction of the performance obligation due to the resulting cumulative catch-up in margin in a single period. An equal amount of cost and revenue is recorded when uninstalled materials are controlled by the customer, which is typically when Barnwell has the right to payment for the materials and when the materials are delivered to the customer’s site or location and such materials have been accepted by the customer. Uninstalled materials are held in inventory and included in “Other current assets” on the Company’s Condensed Consolidated Balance Sheets until control is transferred to the customer. When the estimate on a contract indicates a loss, Barnwell records the entire estimated loss in the period the loss becomes known. Contract price and cost estimates are reviewed periodically as work progresses and adjustments proportionate to the costs incurred to date to total estimated costs at completion are reflected in contract revenues in the reporting period when such estimates are revised. The nature of accounting for these contracts is such that refinements of the estimating process for changing conditions and new developments may occur and are characteristic of the process. Many factors can and do change during a contract performance obligation period which can result in a change to contract profitability including differing site conditions (to the extent that contract remedies are unavailable), the availability of skilled contract labor, the performance of major material suppliers, the performance of major subcontractors, unusual weather conditions and unexpected changes in material costs, among others. These factors may result in revisions to costs and income and are recognized in the period in which the revisions become known. Revenue and profit in future periods of contract performance are recognized using the adjusted estimate. Management evaluates the performance of contracts on an individual basis. In the ordinary course of business, but at least quarterly, we prepare updated estimates that may impact the cost and profit or loss for each contract. The cumulative effect of revisions in estimates of the total forecasted revenue and costs, including any unapproved change orders and claims, during the course of the contract is reflected in the accounting period in which the facts that caused the revision become known. Changes in the cost estimates can have a material impact on our consolidated financial statements and are reflected in the results of operations when they become known. To the extent a contract is deemed to have multiple performance obligations, the Company allocates the transaction price of the contract to each performance obligation using its best estimate of the standalone selling price of each distinct good or service in the contract. Billings in excess of costs and estimated earnings represent advanced billings on certain drilling and pump contracts and are included in “Other current liabilities” on the Company’s Condensed Consolidated Balance Sheets. Costs and estimated earnings in excess of billings represent certain amounts under customer contracts that were earned and billable, but yet not invoiced, and are included in “Other current assets” on the Company’s Condensed Consolidated Balance Sheets. Significant Accounting Policies Other than the change to Barnwell's “Revenue Recognition” policy noted above, there have been no other changes to Barnwell’s significant accounting policies as described in the Notes to Consolidated Financial Statements included in Item 8 of the Company’s most recently filed Annual Report on Form 10-K. Recently Adopted Accounting Pronouncements In May 2014, the Financial Accounting Standards Board (“FASB”) issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606),” which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The impacts of Topic 606 on Barnwell are described in the “Revenue Recognition” accounting policy noted above as well as Note 7. In January 2016, the FASB issued ASU No. 2016-01, "Recognition and Measurement of Financial Assets and Financial Liabilities," which provides guidance for the recognition, measurement, presentation, and disclosure of financial assets and liabilities. The Company adopted the provisions of this ASU effective October 1, 2018. The adoption of this update did not have an impact on Barnwell's consolidated financial statements. In August 2016, the FASB issued ASU No. 2016-15, “Classification of Certain Cash Receipts and Cash Payments,” which addresses the classification of certain specific cash flow issues including debt prepayment or extinguishment costs, settlement of certain debt instruments, contingent consideration payments made after a business combination, proceeds from the settlement of certain insurance claims and distributions received from equity method investees. The Company adopted the provisions of this ASU effective October 1, 2018. The adoption of this update did not have an impact on Barnwell's consolidated financial statements. In October 2016, the FASB issued ASU No. 2016-16, “Intra-Entity Transfers of Assets Other Than Inventory,” which provides guidance on recognition of current income tax consequences for intra-entity asset transfers (other than inventory) at the time of transfer. This represents a change from current GAAP, where the consolidated tax consequences of intra-entity asset transfers are deferred until the transferred asset is sold to a third party or otherwise recovered through use. The Company adopted the provisions of this ASU effective October 1, 2018. The adoption of this update did not have an impact on Barnwell's consolidated financial statements. In November 2016, the FASB issued ASU No. 2016-18, "Statement of Cash Flows - Restricted Cash," which requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents and amounts generally described as restricted cash or restricted cash equivalents. Thus, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and the end-of-period total amounts set forth on the statement of cash flows. The Company adopted the provisions of this ASU effective October 1, 2018. The adoption of this update did not have an impact on Barnwell's consolidated financial statements as Barnwell did not have restricted cash at the time of adoption. In February 2017, the FASB issued ASU No. 2017-05, “Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales of Nonfinancial Assets,” which clarifies the scope of Subtopic 610-20 and adds guidance for partial sales of nonfinancial assets. The Company adopted the provisions of this ASU effective October 1, 2018. The adoption of this update did not have an impact on Barnwell's consolidated financial statements. In March 2017, the FASB issued ASU No. 2017-07, “Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” which requires employers to report the service cost component separate from the other components of net pension benefit costs. The changes to the standard require employers to report the service cost component in the same line item as other compensation costs arising from services rendered by employees during the reporting period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside the subtotal of income from operations, if one is presented. If a separate line item is not used, the line item used in the income statement must be disclosed. The Company adopted the provisions of this ASU effective October 1, 2018. The adoption of this update changed the disclosure of net pension benefit costs in Note 5. In May 2017, the FASB issued ASU No. 2017-09, “Stock Compensation - Scope of Modification Accounting,” which provides clarification on when modification accounting should be used for changes to the terms or conditions of a share-based payment award. The Company adopted the provisions of this ASU effective October 1, 2018. The adoption of this update did not have an impact on Barnwell's consolidated financial statements. Impact of Pending Adoption of Significant Accounting Pronouncements In February 2016, the FASB issued ASU No. 2016-02, “Leases,” which seeks to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and by disclosing key information about leasing arrangements. In general, a right-of-use asset and lease obligation will be recorded for leases exceeding a twelve-month term whether operating or financing, while the income statement will reflect lease expense for operating leases and amortization/interest expense for financing leases. The balance sheet amount recorded for existing leases at the date of adoption must be calculated using the applicable incremental borrowing rate at the date of adoption. Subsequent to the issuance of ASU No. 2016-02, the FASB issued ASU No. 2018-01, “Land Easement Practical Expedient for Transition to Topic 842,” which provides an optional transition practical expedient to not evaluate existing or expired land easements under the new lease standard, ASU No. 2018-10, “Clarifying Pre-Effective Amendments to the Forthcoming Lease Accounting Rules,” which provides further clarification on certain guidance within ASU No. 2016-02, “Leases,” and ASU No. 2018-11, “Leases (Topic 842) - Targeted Improvements,” which allows for a transitional method of adopting the new lease standard. These ASUs are effective for annual reporting periods beginning after December 15, 2018, and interim periods within those annual periods, and allow for the use of either a full retrospective approach for all periods presented in the period of adoption, or a modified retrospective transition approach. Barnwell is currently evaluating the effect that the adoption of this update will have on the consolidated financial statements. |
LOSS PER COMMON SHARE
LOSS PER COMMON SHARE | 3 Months Ended |
Dec. 31, 2018 | |
Earnings Per Share [Abstract] | |
LOSS PER COMMON SHARE | LOSS PER COMMON SHARE Basic loss per share is computed using the weighted-average number of common shares outstanding for the period. Diluted loss per share is calculated using the treasury stock method to reflect the assumed issuance of common shares for all potentially dilutive securities, which consist of outstanding stock options. Potentially dilutive shares are excluded from the computation of diluted loss per share if their effect is anti-dilutive. Options to purchase 318,750 and 493,750 shares of common stock were excluded from the computation of diluted shares for the three months ended December 31, 2018 and 2017 , respectively, as their inclusion would have been anti-dilutive. Reconciliations between net loss attributable to Barnwell stockholders and common shares outstanding of the basic and diluted net loss per share computations are detailed in the following tables: Three months ended December 31, 2018 Net Loss (Numerator) Shares (Denominator) Per-Share Amount Basic net loss per share $ (4,600,000 ) 8,277,160 $ (0.56 ) Effect of dilutive securities - common stock options — — Diluted net loss per share $ (4,600,000 ) 8,277,160 $ (0.56 ) Three months ended December 31, 2017 Net Loss (Numerator) Shares (Denominator) Per-Share Amount Basic net loss per share $ (1,017,000 ) 8,277,160 $ (0.12 ) Effect of dilutive securities - common stock options — — Diluted net loss per share $ (1,017,000 ) 8,277,160 $ (0.12 ) |
INVESTMENTS
INVESTMENTS | 3 Months Ended |
Dec. 31, 2018 | |
Investments, All Other Investments [Abstract] | |
INVESTMENTS | INVESTMENTS A summary of Barnwell’s non-current investments is as follows: December 31, 2018 September 30, 2018 Investment in Kukio Resort Land Development Partnerships $ 1,127,000 $ 1,558,000 Investment in leasehold land interest – Lot 4C 50,000 50,000 Total non-current investments $ 1,177,000 $ 1,608,000 Investment in Kukio Resort Land Development Partnerships On November 27, 2013, Barnwell, through a wholly-owned subsidiary, entered into two limited liability limited partnerships, KD Kona 2013 LLLP and KKM Makai, LLLP ("KKM"), and indirectly acquired a 19.6% non-controlling ownership interest in each of KD Kukio Resorts, LLLP, KD Maniniowali, LLLP and KD Kaupulehu, LLLP ("KDK") for $5,140,000 . These entities, collectively referred to hereinafter as the “Kukio Resort Land Development Partnerships,” own certain real estate and development rights interests in the Kukio, Maniniowali and Kaupulehu portions of Kukio Resort, a private residential community on the Kona coast of the island of Hawaii, as well as Kukio Resort’s real estate sales office operations. KDK holds interests in KD Acquisition, LLLP (“KD I”) and KD Acquisition II, LP, formerly KD Acquisition II, LLLP (“KD II”). KD I is the developer of Kaupulehu Lot 4A Increment I (“Increment I”), and KD II is the developer of Kaupulehu Lot 4A Increment II (“Increment II”). Barnwell's ownership interests in the Kukio Resort Land Development Partnerships is accounted for using the equity method of accounting. The partnerships derive income from the sale of residential parcels, of which 19 lots remain to be sold at Increment I as of December 31, 2018 , as well as from commissions on real estate sales by the real estate sales office. During the three months ended December 31, 2018 , Barnwell received net cash distributions in the amount of $314,000 from the Kukio Resort Land Development Partnerships after distributing $38,000 to non-controlling interests. There were no cash distributions from the Kukio Resort Land Development Partnership for the three months ended December 31, 2017 . Barnwell has the right to receive distributions from its non-controlling interest in KKM in proportion to its partner capital sharing ratio of 34.45% . Barnwell is entitled to a 100% preferred return up to $1,000,000 from KKM on any allocated equity in income of the Kukio Resort Land Development Partnerships for cumulative distributions to all of its partners in excess of $45,000,000 from those partnerships. With the distribution in the three months ended December 31, 2018 , cumulative distributions from the Kukio Resort Land Development Partnerships totaled $45,000,000 . Because we have no control over the distributions from the Kukio Resort Land Development Partnerships and the ability of the Kukio Resort Land Development Partnerships to make such distributions is dependent upon their future sales of lots, we have not recorded any estimated potential preferred return from KKM in our equity in income to date. However, if sufficient distributions are made by the Kukio Resort Land Development Partnerships in the future, Barnwell will have equity in income of affiliates for the recognition of the preferred return. There is no assurance that any future distributions and resulting preferred returns will occur. Equity in loss of affiliates was $79,000 and $153,000 for the three months ended December 31, 2018 and 2017, respectively. The equity in the underlying net assets of the Kukio Resort Land Development Partnerships exceeds the carrying value of the investment in affiliates by approximately $313,000 as of December 31, 2018 , which is attributable to differences in the value of capitalized development costs and a note receivable. The basis difference will be recognized as the partnerships sell lots and recognize the associated costs and sell memberships for the Kuki`o Golf and Beach Club for which the receivable relates. The basis difference adjustments of $1,000 and $3,000 , for the three months ended December 31, 2018 and 2017 , respectively, increased equity in income of affiliates. Summarized financial information for the Kukio Resort Land Development partnerships is as follows: Three months ended 2018 2017 Revenue $ 1,948,000 $ 1,560,000 Gross profit $ 646,000 $ 686,000 Net loss $ (158,000 ) $ (503,000 ) Sale of Interest in Leasehold Land Kaupulehu Developments has the right to receive payments from KD I and KD II resulting from the sale of lots and/or residential units within Increment I and Increment II by KD I and KD II (see Note 12). With respect to Increment I, Kaupulehu Developments is entitled to receive payments from KD I based on the following percentages of the gross receipts from KD I’s sales of single-family residential lots in Increment I: 10% of such aggregate gross proceeds greater than $100,000,000 up to $300,000,000 ; and 14% of such aggregate gross proceeds in excess of $300,000,000 . During the three months ended December 31, 2018 , one single-family lot in Increment I was sold bringing the total amount of gross proceeds from single-family lot sales through December 31, 2018 to $216,400,000 . As of December 31, 2018 , 19 single-family lots, of the 80 lots developed within Increment I, remained to be sold. Under the terms of the Increment II agreement with KD II, Kaupulehu Developments is entitled to receive payments from KD II resulting from the sale of lots and/or residential units by KD II within Increment II. The payments are based on a percentage of gross receipts from KD II's sales ranging from 8% to 10% of the price of improved or unimproved lots or 2.60% to 3.25% of the price of units constructed on a lot, to be determined in the future depending upon a number of variables, including whether the lots are sold prior to improvement. Two ocean front parcels approximately two to three acres in size fronting the ocean were developed within Increment II by KD II, of which one was sold in fiscal 2017 and one was sold in fiscal 2016. The remaining acreage within Increment II is not yet under development. Kaupulehu Developments is also entitled to receive 50% of distributions otherwise payable from KD II to its members after the members of KD II have received distributions equal to the original basis of capital invested in the project, up to $8,000,000 . As of December 31, 2018 , a cumulative total of $3,500,000 was received from KD II under this arrangement, out of the $8,000,000 maximum. The arrangement also includes the rights to three single-family residential lots in Phase 2 of Increment II when developed, at no cost to Barnwell, with a commitment by Barnwell to begin to construct a residence upon each lot within six months of transfer. These lots were not yet developed as of December 31, 2018 . The following table summarizes Increment I and Increment II revenues from KD I and KD II and the amount of fees directly related to such revenues: Three months ended 2018 2017 Sale of interest in leasehold land: Revenues - sale of interest in leasehold land $ 165,000 $ — Fees - included in general and administrative expenses (20,000 ) — Sale of interest in leasehold land, net of fees $ 145,000 $ — There is no assurance with regards to the amounts of future payments from Increment I or Increment II to be received. Kaupulehu Developments is obligated to pay a 10.4% to 11.6% fee to unrelated third parties on its revenues. Investment in Leasehold Land Interest - Lot 4C Kaupulehu Developments holds an interest in an area of approximately 1,000 acres of vacant leasehold land zoned conservation located adjacent to Lot 4A, which currently has no development potential without both a development agreement with the lessor and zoning reclassification. The lease terminates in December 2025. |
OIL AND NATURAL GAS PROPERTIES
OIL AND NATURAL GAS PROPERTIES | 3 Months Ended |
Dec. 31, 2018 | |
Oil and Natural Gas Properties [Abstract] | |
OIL AND NATURAL GAS PROPERTIES | OIL AND NATURAL GAS PROPERTIES Full cost properties In October 2017, Barnwell entered into a Purchase and Sale Agreement with an independent third party and sold its oil and natural gas properties located in the Pouce Coupe area of Alberta, Canada. The sales price per the agreement was adjusted to $72,000 for customary purchase price adjustments to reflect the economic activity from the effective date of May 1, 2017 to the closing date. From Barnwell's net proceeds, $37,000 was withheld and remitted by the buyer to the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes. No gain or loss was recognized on this sale as it did not result in a significant alteration of the relationship between capitalized costs and proved reserves. Proceeds from the disposition were credited to the full cost pool. During the quarter ended December 31, 2018, Barnwell acquired additional working interests in oil and natural gas properties located in the Wood River and Twining areas of Alberta, Canada for cash consideration of $355,000 . The purchase price per the agreements were adjusted for customary purchase price adjustments to reflect the economic activity from the effective date to the closing date. The final determination of the customary adjustments to the purchase price has not yet been made however it is not expected to result in a material adjustment. The $633,000 of proceeds from sale of oil and gas properties included in the Condensed Consolidated Statement of Cash Flows for the three months ended December 31, 2018 represents the refund of income taxes previously withheld from what otherwise would have been proceeds on prior years' oil and gas property sales. Under the full cost method of accounting, the Company performs quarterly oil and natural gas ceiling test calculations. Barnwell's net capitalized costs exceeded the ceiling limitations at December 31, 2018. As such, Barnwell reduced the carrying value of its oil and natural gas properties by $2,170,000 during the three months ended December 31, 2018. Changes in the 12-month rolling average first-day-of-the-month prices for oil, natural gas and natural gas liquids prices, the value of reserve additions as compared to the amount of capital expenditures to obtain them, and changes in production rates and estimated levels of reserves, future development costs and the market value of unproved properties, impact the determination of the maximum carrying value of oil and natural gas properties. Based on the 12-month rolling average first-day-of-the-month prices for January and February 2019, it is reasonably possible that we will incur a further ceiling test impairment in the Company's second quarter ending March 31, 2019. The Company is currently unable to estimate a range of the amount of any potential future reduction in carrying value as variables that impact the ceiling limitation are dependent upon actual results through the end of March 2019. |
RETIREMENT PLANS
RETIREMENT PLANS | 3 Months Ended |
Dec. 31, 2018 | |
Retirement Benefits [Abstract] | |
RETIREMENT PLANS | RETIREMENT PLANS Barnwell sponsors a noncontributory defined benefit pension plan (“Pension Plan”) covering substantially all of its U.S. employees. Additionally, Barnwell sponsors a Supplemental Employee Retirement Plan (“SERP”), a noncontributory supplemental retirement benefit plan which covers certain current and former employees of Barnwell for amounts exceeding the limits allowed under the Pension Plan, and a postretirement medical insurance benefits plan (“Postretirement Medical”) covering eligible U.S. employees. The following table details the components of net periodic benefit (income) cost for Barnwell’s retirement plans: Pension Plan SERP Postretirement Medical Three months ended December 31, 2018 2017 2018 2017 2018 2017 Service cost $ 50,000 $ 53,000 $ 9,000 $ 6,000 $ — $ — Interest cost 93,000 89,000 21,000 15,000 25,000 19,000 Expected return on plan assets (161,000 ) (147,000 ) — — — — Amortization of prior service cost (credit) 1,000 1,000 (1,000 ) (1,000 ) — — Amortization of net actuarial loss 3,000 21,000 1,000 — 13,000 3,000 Net periodic benefit (income) cost $ (14,000 ) $ 17,000 $ 30,000 $ 20,000 $ 38,000 $ 22,000 The components of net periodic benefit (income) cost, including service cost, are included in “General and administrative” expenses in the Company's Condensed Consolidated Statements of Operations. Barnwell estimates that it will make approximately $150,000 in contributions to the Pension Plan during fiscal 2019 . The SERP and Postretirement Medical plans are unfunded, and Barnwell funds benefits when payments are made. Expected payments under the Postretirement Medical plan and the SERP for fiscal 2019 are not material. Fluctuations in actual equity market returns as well as changes in general interest rates will result in changes in the market value of plan assets and may result in increased or decreased retirement benefits costs and contributions in future periods. |
INCOME TAXES
INCOME TAXES | 3 Months Ended |
Dec. 31, 2018 | |
Income Tax Disclosure [Abstract] | |
INCOME TAXES | INCOME TAXES The components of loss before income taxes, after adjusting the loss for non-controlling interests, are as follows Three months ended 2018 2017 United States $ (1,124,000 ) $ (1,143,000 ) Canada (3,581,000 ) (377,000 ) $ (4,705,000 ) $ (1,520,000 ) The components of the income tax benefit are as follows: Three months ended 2018 2017 Current $ (33,000 ) $ (573,000 ) Deferred (72,000 ) 70,000 $ (105,000 ) $ (503,000 ) Consolidated taxes do not bear a customary relationship to pretax results due primarily to the fact that the Company is taxed separately in Canada based on Canadian source operations and in the U.S. based on consolidated operations, and essentially all deferred tax assets, net of relevant offsetting deferred tax liabilities and any amounts estimated to be realizable through tax carryback strategies, are not estimated to have a future benefit as tax credits or deductions. Income from our non-controlling interest in the Kukio Resort Land Development Partnerships is treated as non-unitary for state of Hawaii unitary filing purposes, thus unitary Hawaii losses provide limited sheltering of such non-unitary income. The repeal of the corporate Alternative Minimum Tax ("AMT") by the Tax Cuts and Jobs Act of 2017 (“TCJA”), enacted on December 22, 2017, provides a mechanism for the refund over time of any unused AMT credit carryovers. Prior to the enactment of the TCJA, it was not more likely than not that the Company’s AMT credit carryovers would provide a future benefit, as such the AMT deferred tax asset had a full valuation allowance. As a result of the new TCJA provision for refundability of the AMT, the Company recorded a current income tax benefit of $460,000 in the quarter ended December 31, 2017 to reflect the undiscounted unused AMT credit carryover balance as a non-current income tax receivable. There was no significant impact of the TCJA during the quarter ended December 31, 2018. Respective portions of this balance will be reclassified to current income taxes receivable when amounts are eligible for refund within one year of the balance sheet date. |
REVENUE FROM CONTRACTS WITH CUS
REVENUE FROM CONTRACTS WITH CUSTOMERS REVENUE FROM CONTACTS WITH CUSTOMERS | 3 Months Ended |
Dec. 31, 2018 | |
Revenue from Contract with Customer [Abstract] | |
REVENUE FROM CONTRACTS WITH CUSTOMERS | REVENUE FROM CONTRACTS WITH CUSTOMERS Adoption On October 1, 2018, the Company adopted Topic 606 using the modified retrospective method applied to all contracts. Results for operating periods beginning October 1, 2018 are presented under Topic 606, while prior period amounts are not adjusted and continue to be reported under the accounting standards in effect for the prior period. Changes in other current assets and other current liabilities are primarily due to Topic 606's required treatment for the contract drilling segment's uninstalled materials and the related impact on billings in excess of costs and estimated earnings, which is now referred to as contract liabilities. Additionally, the Company recorded a net increase to beginning retained earnings of $20,000 as of October 1, 2018 due to the cumulative impact of adopting Topic 606, as detailed below. The increase to beginning retained earnings was due entirely to the impact of adoption of Topic 606 on the contract drilling business segment. October 1, 2018 Pre-606 Balances 606 Adjustments Adjusted Balances ASSETS Current assets: Accounts and other receivables, net of allowance for doubtful accounts $ 1,965,000 $ (308,000 ) $ 1,657,000 Other current assets 950,000 687,000 1,637,000 LIABILITIES AND EQUITY Current liabilities: Other current liabilities 54,000 359,000 413,000 Equity: Retained earnings 13,253,000 20,000 13,273,000 In accordance with Topic 606, the disclosure of the impact of adoption to the Company’s Condensed Consolidated Statements of Operations and Condensed Consolidated Balance Sheets was as shown below. There were no impacts to the oil and natural gas or land investment segments. Three months ended December 31, 2018 Impact of changes in accounting policies As Reported Balances without adoption of Topic 606 Effect of change increase (decrease) Revenues: Contract drilling $ 1,163,000 $ 741,000 $ 422,000 Costs and expenses: Contract drilling operating 1,316,000 893,000 423,000 Loss before equity in loss of affiliates and income taxes (4,599,000 ) (4,598,000 ) (1,000 ) Loss before income taxes (4,678,000 ) (4,677,000 ) (1,000 ) Net loss (4,573,000 ) (4,572,000 ) (1,000 ) Less: Net earnings attributable to non-controlling interests 27,000 27,000 — Net loss attributable to Barnwell Industries, Inc. stockholders $ (4,600,000 ) $ (4,599,000 ) $ (1,000 ) Basic and diluted net loss per common share attributable to Barnwell Industries, Inc. stockholders $ (0.56 ) $ (0.56 ) $ — December 31, 2018 Impact of changes in accounting policies As Reported Balances without adoption of Topic 606 Effect of change increase (decrease) ASSETS Current assets: Accounts and other receivables, net of allowance for doubtful accounts $ 1,465,000 $ 1,819,000 $ (354,000 ) Other current assets 1,765,000 1,031,000 734,000 LIABILITIES AND EQUITY Current liabilities: Other current liabilities 452,000 91,000 361,000 Equity: Retained earnings 8,673,000 8,654,000 19,000 The impact in revenue recognition due to the adoption of Topic 606 is primarily from the timing of revenue recognition for uninstalled materials. Refer to Note 1 “Summary of Significant Accounting Policies” for a summary of the Company’s significant policies for revenue recognition. Disaggregation of Revenue The following table provides information about disaggregated revenue by revenue streams, reportable segments, geographical region, and timing of revenue recognition for the three months ended December 31, 2018. Three months ended December 31, 2018 Oil and natural gas Contract drilling Land investment Other Total Revenue streams: Oil $ 896,000 $ — $ — $ — $ 896,000 Natural gas 162,000 — — — 162,000 Natural gas liquids 174,000 — — — 174,000 Drilling and pump — 1,163,000 — — 1,163,000 Contingent residual payments — — 165,000 — 165,000 Other — — — 14,000 14,000 Total revenues before interest income $ 1,232,000 $ 1,163,000 $ 165,000 $ 14,000 $ 2,574,000 Geographical regions: United States $ — $ 1,163,000 $ 165,000 $ — $ 1,328,000 Canada 1,232,000 — — 14,000 1,246,000 Total revenues before interest income $ 1,232,000 $ 1,163,000 $ 165,000 $ 14,000 $ 2,574,000 Timing of revenue recognition: Goods transferred at a point in time $ 1,232,000 $ — $ 165,000 $ 14,000 $ 1,411,000 Services transferred over time — 1,163,000 — — 1,163,000 Total revenues before interest income $ 1,232,000 $ 1,163,000 $ 165,000 $ 14,000 $ 2,574,000 Contract Balances The following table provides information about accounts receivables, contract assets and contract liabilities from contracts with customers: October 1, 2018 December 31, 2018 Accounts receivables from contracts with customers $ 1,245,000 $ 1,074,000 Contract assets 267,000 405,000 Contract liabilities 400,000 441,000 Accounts receivables from contracts with customers are included in "Accounts and other receivables, net of allowance for doubtful accounts," and contract assets, which includes costs and estimated earnings in excess of billings and retainage, are included in “Other current assets.” Contract liabilities, which includes billings in excess of costs and estimated earnings are included in “Other current liabilities” in the accompanying Condensed Consolidated Balance Sheets. Retainage, included in contract assets, represents amounts due from customers, but where payments are withheld contractually until certain construction milestones are met. Amounts retained typically range from 5% to 10% of the total invoice, up to contractually-specified maximums. The Company classifies as a current asset those retainages that are expected to be collected in the next twelve months. Contract assets represent the Company’s rights to consideration in exchange for services transferred to a customer that have not been billed as of the reporting date. The Company’s rights are generally unconditional at the time its performance obligations are satisfied. When the Company receives consideration, or such consideration is unconditionally due, from a customer prior to transferring goods or services to the customer under the terms of a sales contract, the Company records deferred revenue, which represents a contract liability. Such deferred revenue typically results from billings in excess of costs and estimated earnings on uncompleted contracts. As of December 31, 2018, the Company had $441,000 included in “Other current liabilities” on the Condensed Consolidated Balance Sheets for those performance obligations expected to be completed in the next twelve months. The change in contract assets and liabilities was due primarily to normal business operations. For the quarter ended December 31, 2018, the Company recognized revenue of $21,000 that was previously included in the beginning balance of contract liabilities. Changes in contract liabilities are also driven by reclassifications to or from contract assets as a result of differences in the timing of current period revenue recognition and customer billings. Contracts are sometimes modified for a change in scope or other requirements. The Company considers contract modifications to exist when the modification either creates new or changes the existing enforceable rights and obligations. Most of the Company’s contract modifications are for goods and services that are not distinct from the existing performance obligations. The effect of a contract modification on the transaction price, and the measure of progress for the performance obligation to which it relates, is recognized as an adjustment to revenue (either as an increase or decrease) on a cumulative catchup basis. The Company elected to utilize the modified retrospective transition practical expedient which allows the Company to evaluate the impact of contract modifications as of the adoption date rather than evaluating the impact of the modifications at the time they occurred prior to the adoption date. Given the nature of our typical contract modifications, which are generally limited to contract price change orders and extensions of time, the effect of the use of this practical expedient is not estimated to be significant. Performance Obligations A performance obligation is a promise in a contract to transfer a distinct good or service to the customer, and is the unit of account in Topic 606. Performance obligations are satisfied as of a point in time or over time and are supported by contracts with customers. The Company's contract drilling segment recognizes revenues over time. For most of the Company’s well drilling and pump installation and repair contracts, there are multiple promises of good or services. Typically, the Company provides a significant service of integrating a complex set of tasks and components such as site preparation, well drilling/pump installation, and testing for a project contract. The bundle of goods and services are provided to deliver one output for which the customer has contracted. In these cases, the Company considers the bundle of goods and services to be a single performance obligation. If the contract is separated into more than one performance obligation, the Company allocates the total transaction price to each performance obligation in an amount based on the estimated relative standalone selling prices of the promised goods or services underlying each performance obligation. For the oil and natural gas segment, revenues are recognized at a point in time and the performance obligation is considered satisfied when oil, natural gas and natural gas liquids are delivered and control has passed to the customer. This is generally at the time the customer obtains legal title to the product and when it is physically transferred to the contractual delivery point. For the land investment segment, which recognizes revenues at a point in time, the performance obligation is considered satisfied when the contingent residual payment revenue recognition criteria has been met and we release any previously retained right to such contingent residual payment. There are no significant or unusual payment terms related to Barnwell’s oil and natural gas or land investment segments. For Barnwell’s contract drilling segment, customer contracts determine payment terms which typically allow for progress payments and 5% to 10% retainage. For the contract drilling contracts, Barnwell typically serves as the principal and records related revenue and expenses on a gross basis. In the unusual circumstances where Barnwell acts as an agent, the related revenues and expenses are recognized on a net basis. Barnwell does not typically provide extended warranties on well drilling or pump contracts beyond the normal assurance-type warranties that the product complies with agreed upon specifications. For oil and natural gas contracts, Barnwell evaluates its arrangements with third parties and partners to determine if the Company acts as the principal or as an agent. In making this evaluation, management considers if Barnwell retains control of the product being delivered to the end customer. As part of this assessment, management considers whether the Company retains the economic benefits associated with the good being delivered to the end customer. Management also considers whether the Company has the primary responsibility for the delivery of the product, the ability to establish prices or the inventory risk. If Barnwell acts in the capacity of an agent rather than as a principal in a transaction, then the revenue is recognized on a net basis, only reflecting the fee, if any, realized by the Company from the transaction. Backlog - The Company’s remaining performance obligations for drilling and pump installation contracts (hereafter referred to as “backlog”) represent the unrecognized revenue value of the Company’s contract commitments. The Company’s backlog may vary significantly each reporting period based on the timing of major new contract commitments. In addition, our customers have the right, under some infrequent circumstances, to terminate contracts or defer the timing of the Company’s services and their payments to us. At December 31, 2018, the Company had backlog of approximately $5,738,000 . Approximately 66% of our December 31, 2018 backlog is anticipated to be recognized as revenue in the next twelve months and the remaining, thereafter. Contract Fulfillment Costs In connection with the adoption of Topic 606, the Company is required to account for certain fulfillment costs over the life of the contract, consisting primarily of preconstruction costs such as set-up and mobilization costs. Preconstruction costs are capitalized and allocated across all performance obligations and deferred and amortized over the contract term on a progress towards completion basis. As of December 31, 2018, the Company had $88,000 in unamortized preconstruction costs related to contracts that were not completed. During the three months ended December 31, 2018, the amortization of preconstruction costs related to contracts were not material and have been included in the accompanying Condensed Consolidated Statements of Operations. Additionally, no impairment charges in connection with the Company’s preconstruction costs were recorded during the period ended December 31, 2018. |
SEGMENT INFORMATION
SEGMENT INFORMATION | 3 Months Ended |
Dec. 31, 2018 | |
Segment Reporting [Abstract] | |
SEGMENT INFORMATION | SEGMENT INFORMATION Barnwell operates the following segments: 1) acquiring, developing, producing and selling oil and natural gas in Canada (oil and natural gas); 2) investing in land interests in Hawaii (land investment); and 3) drilling wells and installing and repairing water pumping systems in Hawaii (contract drilling). The following table presents certain financial information related to Barnwell’s reporting segments. All revenues reported are from external customers with no intersegment sales or transfers. Three months ended 2018 2017 Revenues: Oil and natural gas $ 1,232,000 $ 953,000 Contract drilling 1,163,000 842,000 Land investment 165,000 — Other 14,000 28,000 Total before interest income 2,574,000 1,823,000 Interest income 21,000 33,000 Total revenues $ 2,595,000 $ 1,856,000 Depletion, depreciation, and amortization: Oil and natural gas $ 749,000 $ 199,000 Contract drilling 57,000 61,000 Other 13,000 20,000 Total depletion, depreciation, and amortization $ 819,000 $ 280,000 Impairment: Oil and natural gas $ 2,170,000 $ — Total impairment $ 2,170,000 $ — Operating (loss) profit (before general and administrative expenses): Oil and natural gas $ (3,024,000 ) $ 96,000 Land investment 165,000 — Contract drilling (210,000 ) (40,000 ) Other 1,000 8,000 Total operating (loss) profit (3,068,000 ) 64,000 Equity in loss of affiliates: Land investment (79,000 ) (153,000 ) General and administrative expenses (1,548,000 ) (1,481,000 ) Interest expense (4,000 ) — Interest income 21,000 33,000 Loss before income taxes $ (4,678,000 ) $ (1,537,000 ) |
ACCUMULATED OTHER COMPREHENSIVE
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) | 3 Months Ended |
Dec. 31, 2018 | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] | |
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) | ACCUMULATED OTHER COMPREHENSIVE LOSS The changes in each component of accumulated other comprehensive loss were as follows: Three months ended 2018 2017 Foreign currency translation: Beginning accumulated foreign currency translation $ 925,000 $ 1,053,000 Change in cumulative translation adjustment before reclassifications (413,000 ) (6,000 ) Income taxes — — Net current period other comprehensive loss (413,000 ) (6,000 ) Ending accumulated foreign currency translation 512,000 1,047,000 Retirement plans: Beginning accumulated retirement plans benefit cost (1,439,000 ) (2,111,000 ) Amortization of net actuarial loss and prior service cost 17,000 24,000 Income taxes — — Net current period other comprehensive income 17,000 24,000 Ending accumulated retirement plans benefit cost (1,422,000 ) (2,087,000 ) Accumulated other comprehensive loss, net of taxes $ (910,000 ) $ (1,040,000 ) The amortization of accumulated other comprehensive loss components for the retirement plans are included in the computation of net periodic benefit (income) cost which is a component of “General and administrative” expenses on the accompanying Condensed Consolidated Statements of Operations (see Note 5 for additional details). |
FAIR VALUE MEASUREMENTS
FAIR VALUE MEASUREMENTS | 3 Months Ended |
Dec. 31, 2018 | |
Fair Value Disclosures [Abstract] | |
FAIR VALUE MEASUREMENTS | FAIR VALUE MEASUREMENTS The carrying values of cash and cash equivalents, certificates of deposit, accounts and other receivables, accounts payable and accrued current liabilities approximate their fair values due to the short-term nature of the instruments. Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis The estimated fair values of oil and natural gas properties and the asset retirement obligation incurred in the drilling of oil and natural gas wells or assumed in the acquisitions of additional oil and natural gas working interests are based on an estimated discounted cash flow model and market assumptions. The significant Level 3 assumptions used in the calculation of estimated discounted cash flows included future commodity prices, projections of estimated quantities of oil and natural gas reserves, expectations for timing and amount of future development, operating and asset retirement costs, projections of future rates of production, expected recovery rates and risk adjusted discount rates. Barnwell estimates the fair value of asset retirement obligations based on the projected discounted future cash outflows required to settle abandonment and restoration liabilities. Such an estimate requires assumptions and judgments regarding the existence of liabilities, the amount and timing of cash outflows required to settle the liability, what constitutes adequate restoration, inflation factors, credit adjusted discount rates, and consideration of changes in legal, regulatory, environmental and political environments. Abandonment and restoration cost estimates are determined in conjunction with Barnwell’s reserve engineers based on historical information regarding costs incurred to abandon and restore similar well sites, information regarding current market conditions and costs, and knowledge of subject well sites and properties. Asset retirement obligation fair value measurements in the current period were Level 3 fair value measurements. |
INFORMATION RELATING TO THE CON
INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS | 3 Months Ended |
Dec. 31, 2018 | |
Supplemental Cash Flow Elements [Abstract] | |
INFORMATION RELATING TO THE CONSOLIDATED STATEMENTS OF CASH FLOWS | INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS Three months ended 2018 2017 Supplemental disclosure of cash flow information: Cash paid (received) during the year for: Income taxes received $ (866,000 ) $ — Supplemental disclosure of non-cash investing activities: Canadian income tax withholding on proceeds from the sale of oil and natural gas properties $ — $ 37,000 Capital expenditure accruals related to oil and natural gas exploration and development decreased $66,000 during the three months ended December 31, 2018 and increased $30,000 during the three months ended December 31, 2017 . Additionally, capital expenditure accruals related to oil and natural gas asset retirement obligations increased $146,000 during the three months ended December 31, 2018 and decreased $30,000 during the three months ended December 31, 2017 . |
RELATED PARTY TRANSACTIONS
RELATED PARTY TRANSACTIONS | 3 Months Ended |
Dec. 31, 2018 | |
Related Party Transactions [Abstract] | |
RELATED PARTY TRANSACTIONS | RELATED PARTY TRANSACTIONS Kaupulehu Developments is entitled to receive a percentage of the gross receipts from the sales of lots in Increment I from KD I and the sales of lots and/or residential units in Increment II from KD II. Kaupulehu Developments is also entitled to receive 50% of any future distributions otherwise payable from KD II to its members up to $8,000,000 , of which $3,500,000 has been received to date. KD I and KD II are part of the Kukio Resort Land Development Partnerships in which Barnwell holds an indirect 19.6% non-controlling ownership interest accounted for under the equity method of investment. The percentage of sales payments and percent of distribution payments are part of transactions which took place in 2004 and 2006 where Kaupulehu Developments sold its leasehold interests in Increment I and Increment II to KD I's and KD II's predecessors in interest, respectively, which was prior to Barnwell’s affiliation with KD I and KD II which commenced on November 27, 2013, the acquisition date of our ownership interest in the Kukio Resort Land Development Partnerships. During the three months ended December 31, 2018 , Barnwell received $165,000 in percentage of sales payments from KD II from the sale of one lot within Increment II. No lots were sold during the three months ended December 31, 2017. |
SUMMARY OF SIGNIFICANT ACCOUN_2
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies) | 3 Months Ended |
Dec. 31, 2018 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Principles of Consolidation | Principles of Consolidation The condensed consolidated financial statements include the accounts of Barnwell Industries, Inc. and all majority-owned subsidiaries (collectively referred to herein as “Barnwell,” “we,” “our,” “us,” or the “Company”), including a 77.6% -owned land investment general partnership (Kaupulehu Developments), a 75% -owned land investment partnership (KD Kona 2013 LLLP) and an 80% -owned joint venture (Kaupulehu 2007, LLLP). All significant intercompany accounts and transactions have been eliminated. Undivided interests in oil and natural gas exploration and production joint ventures are consolidated on a proportionate basis. Barnwell’s investments in both unconsolidated entities in which a significant, but less than controlling, interest is held and in variable interest entities in which the Company is not deemed to be the primary beneficiary are accounted for by the equity method. Unless otherwise indicated, all references to “dollars” in this Form 10-Q are to U.S. dollars. |
Unaudited Interim Financial Information | Unaudited Interim Financial Information The accompanying unaudited condensed consolidated financial statements and notes have been prepared by Barnwell in accordance with the rules and regulations of the United States (“U.S.”) Securities and Exchange Commission. Accordingly, certain information and footnote disclosures normally included in the annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted pursuant to those rules and regulations, although the Company believes that the disclosures made are adequate to make the information not misleading. These condensed consolidated financial statements and notes should be read in conjunction with the consolidated financial statements and notes thereto included in Barnwell’s September 30, 2018 Annual Report on Form 10-K. The Condensed Consolidated Balance Sheet as of September 30, 2018 has been derived from audited consolidated financial statements. In the opinion of management, all adjustments (which include only normal recurring adjustments) necessary to present fairly the financial position at December 31, 2018 , results of operations, comprehensive loss, equity and cash flows for the three months ended December 31, 2018 and 2017 , have been made. The results of operations for the period ended December 31, 2018 are not necessarily indicative of the operating results for the full year. |
Use of Estimates in the Preparation of Condensed Consolidated Financial Statements | Use of Estimates in the Preparation of Condensed Consolidated Financial Statements The preparation of the condensed consolidated financial statements in conformity with U.S. GAAP requires management of Barnwell to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Actual results could differ significantly from those estimates. Significant assumptions are required in the valuation of deferred tax assets, asset retirement obligations, share-based payment arrangements, obligations for retirement plans, contract drilling estimated costs to complete, proved oil and natural gas reserves, and the carrying value of other assets, and such assumptions may impact the amount at which such items are recorded. |
Revenue Recognition | Revenue Recognition On October 1, 2018, the Company adopted Accounting Standards Updates (“ASU”) No. 2014-09, “Revenue from Contracts with Customers” (“Topic 606”) using the modified retrospective method applied to all contracts. Results for reporting periods beginning October 1, 2018 are presented under Topic 606, while prior period amounts are not adjusted and continue to be reported under the accounting standards in effect for the prior period. The Company recorded an adjustment to retained earnings on October 1, 2018 due to the cumulative impact of adopting Topic 606. See Note 7 “Revenue from Contracts with Customers” for the required disclosures related to the impact of adopting this standard and a discussion of the Company’s updated policies related to revenue recognition discussed below. Barnwell operates in and derives revenue from the following three principal business segments: • Oil and Natural Gas Segment - Barnwell engages in oil and natural gas development, production, acquisitions and sales in Canada. • Land Investment Segment - Barnwell invests in land interests in Hawaii. • Contract Drilling Segment - Barnwell provides well drilling services and water pumping system installation and repairs in Hawaii. Oil and Natural Gas - Barnwell’s investments in oil and natural gas properties are located in Alberta, Canada. These property interests are principally held under governmental leases or licenses. Barnwell sells the large majority of its oil, natural gas and natural gas liquids production under short-term contracts between itself and marketers based on prices indexed to market prices and recognizes revenue at a point in time when the oil, natural gas and natural gas liquids are delivered, as this is where Barnwell’s performance obligation is satisfied and title has passed to the customer. Under Topic 606, there were no changes to revenue recognition for the Oil and Natural Gas segment. Land Investment - Barnwell is entitled to receive contingent residual payments from the entities that previously purchased Barnwell’s land investment interests under contracts entered into in prior years. The residual payments under those contracts become due when the entities sell lots and/or residential units in the areas that were previously sold under the aforementioned contracts or when a preferred payment threshold is achieved. Prior to the adoption of Topic 606, the payments received by Barnwell were deemed contingent revenues under the full accrual method and were recognized as revenues when payment is assured, which was generally when a lot sale occurred or the preferred payments were made. The adoption of Topic 606 did not fundamentally change the way Barnwell recognizes these contingent residual revenue payments due primarily to the variable consideration constraint provision of Topic 606, whereby the constraint is removed only when it is probable that a significant reversal in the amount of cumulative revenue recognized will not occur. As such, there were no significant changes to revenue recognition for the Land Investment segment under Topic 606. Contract Drilling - Through fixed price contracts which are normally less than twelve months in duration, Barnwell drills water and water monitoring wells and installs and repairs water pumping systems in Hawaii. Under the Topic 606 requirements, Barnwell recognizes revenue from well drilling or the installation of pumps over time based on total costs incurred on the projects relative to the total expected costs to satisfy the performance obligation as management believes this is an accurate representation of the percentage of completion as control is continuously transferred to the customer. Uninstalled materials, which typically consists of well casing or pumps, are excluded in the costs-to-costs calculation for the duration of the contract as including these costs would result in a distortion of progress towards satisfaction of the performance obligation due to the resulting cumulative catch-up in margin in a single period. An equal amount of cost and revenue is recorded when uninstalled materials are controlled by the customer, which is typically when Barnwell has the right to payment for the materials and when the materials are delivered to the customer’s site or location and such materials have been accepted by the customer. Uninstalled materials are held in inventory and included in “Other current assets” on the Company’s Condensed Consolidated Balance Sheets until control is transferred to the customer. When the estimate on a contract indicates a loss, Barnwell records the entire estimated loss in the period the loss becomes known. Contract price and cost estimates are reviewed periodically as work progresses and adjustments proportionate to the costs incurred to date to total estimated costs at completion are reflected in contract revenues in the reporting period when such estimates are revised. The nature of accounting for these contracts is such that refinements of the estimating process for changing conditions and new developments may occur and are characteristic of the process. Many factors can and do change during a contract performance obligation period which can result in a change to contract profitability including differing site conditions (to the extent that contract remedies are unavailable), the availability of skilled contract labor, the performance of major material suppliers, the performance of major subcontractors, unusual weather conditions and unexpected changes in material costs, among others. These factors may result in revisions to costs and income and are recognized in the period in which the revisions become known. Revenue and profit in future periods of contract performance are recognized using the adjusted estimate. Management evaluates the performance of contracts on an individual basis. In the ordinary course of business, but at least quarterly, we prepare updated estimates that may impact the cost and profit or loss for each contract. The cumulative effect of revisions in estimates of the total forecasted revenue and costs, including any unapproved change orders and claims, during the course of the contract is reflected in the accounting period in which the facts that caused the revision become known. Changes in the cost estimates can have a material impact on our consolidated financial statements and are reflected in the results of operations when they become known. To the extent a contract is deemed to have multiple performance obligations, the Company allocates the transaction price of the contract to each performance obligation using its best estimate of the standalone selling price of each distinct good or service in the contract. Billings in excess of costs and estimated earnings represent advanced billings on certain drilling and pump contracts and are included in “Other current liabilities” on the Company’s Condensed Consolidated Balance Sheets. Costs and estimated earnings in excess of billings represent certain amounts under customer contracts that were earned and billable, but yet not invoiced, and are included in “Other current assets” on the Company’s Condensed Consolidated Balance Sheets. |
Recently Adopted Accounting Pronouncements and Impact of Pending Adoption of Significant Accounting Pronouncements | Recently Adopted Accounting Pronouncements In May 2014, the Financial Accounting Standards Board (“FASB”) issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606),” which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The impacts of Topic 606 on Barnwell are described in the “Revenue Recognition” accounting policy noted above as well as Note 7. In January 2016, the FASB issued ASU No. 2016-01, "Recognition and Measurement of Financial Assets and Financial Liabilities," which provides guidance for the recognition, measurement, presentation, and disclosure of financial assets and liabilities. The Company adopted the provisions of this ASU effective October 1, 2018. The adoption of this update did not have an impact on Barnwell's consolidated financial statements. In August 2016, the FASB issued ASU No. 2016-15, “Classification of Certain Cash Receipts and Cash Payments,” which addresses the classification of certain specific cash flow issues including debt prepayment or extinguishment costs, settlement of certain debt instruments, contingent consideration payments made after a business combination, proceeds from the settlement of certain insurance claims and distributions received from equity method investees. The Company adopted the provisions of this ASU effective October 1, 2018. The adoption of this update did not have an impact on Barnwell's consolidated financial statements. In October 2016, the FASB issued ASU No. 2016-16, “Intra-Entity Transfers of Assets Other Than Inventory,” which provides guidance on recognition of current income tax consequences for intra-entity asset transfers (other than inventory) at the time of transfer. This represents a change from current GAAP, where the consolidated tax consequences of intra-entity asset transfers are deferred until the transferred asset is sold to a third party or otherwise recovered through use. The Company adopted the provisions of this ASU effective October 1, 2018. The adoption of this update did not have an impact on Barnwell's consolidated financial statements. In November 2016, the FASB issued ASU No. 2016-18, "Statement of Cash Flows - Restricted Cash," which requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents and amounts generally described as restricted cash or restricted cash equivalents. Thus, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and the end-of-period total amounts set forth on the statement of cash flows. The Company adopted the provisions of this ASU effective October 1, 2018. The adoption of this update did not have an impact on Barnwell's consolidated financial statements as Barnwell did not have restricted cash at the time of adoption. In February 2017, the FASB issued ASU No. 2017-05, “Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales of Nonfinancial Assets,” which clarifies the scope of Subtopic 610-20 and adds guidance for partial sales of nonfinancial assets. The Company adopted the provisions of this ASU effective October 1, 2018. The adoption of this update did not have an impact on Barnwell's consolidated financial statements. In March 2017, the FASB issued ASU No. 2017-07, “Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” which requires employers to report the service cost component separate from the other components of net pension benefit costs. The changes to the standard require employers to report the service cost component in the same line item as other compensation costs arising from services rendered by employees during the reporting period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside the subtotal of income from operations, if one is presented. If a separate line item is not used, the line item used in the income statement must be disclosed. The Company adopted the provisions of this ASU effective October 1, 2018. The adoption of this update changed the disclosure of net pension benefit costs in Note 5. In May 2017, the FASB issued ASU No. 2017-09, “Stock Compensation - Scope of Modification Accounting,” which provides clarification on when modification accounting should be used for changes to the terms or conditions of a share-based payment award. The Company adopted the provisions of this ASU effective October 1, 2018. The adoption of this update did not have an impact on Barnwell's consolidated financial statements. Impact of Pending Adoption of Significant Accounting Pronouncements In February 2016, the FASB issued ASU No. 2016-02, “Leases,” which seeks to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and by disclosing key information about leasing arrangements. In general, a right-of-use asset and lease obligation will be recorded for leases exceeding a twelve-month term whether operating or financing, while the income statement will reflect lease expense for operating leases and amortization/interest expense for financing leases. The balance sheet amount recorded for existing leases at the date of adoption must be calculated using the applicable incremental borrowing rate at the date of adoption. Subsequent to the issuance of ASU No. 2016-02, the FASB issued ASU No. 2018-01, “Land Easement Practical Expedient for Transition to Topic 842,” which provides an optional transition practical expedient to not evaluate existing or expired land easements under the new lease standard, ASU No. 2018-10, “Clarifying Pre-Effective Amendments to the Forthcoming Lease Accounting Rules,” which provides further clarification on certain guidance within ASU No. 2016-02, “Leases,” and ASU No. 2018-11, “Leases (Topic 842) - Targeted Improvements,” which allows for a transitional method of adopting the new lease standard. These ASUs are effective for annual reporting periods beginning after December 15, 2018, and interim periods within those annual periods, and allow for the use of either a full retrospective approach for all periods presented in the period of adoption, or a modified retrospective transition approach. Barnwell is currently evaluating the effect that the adoption of this update will have on the consolidated financial statements. |
LOSS PER COMMON SHARE (Tables)
LOSS PER COMMON SHARE (Tables) | 3 Months Ended |
Dec. 31, 2018 | |
Earnings Per Share [Abstract] | |
Reconciliations between net earnings (loss) attributable to the entity's stockholders and common shares outstanding of the basic and diluted net earnings (loss) per share computations | Reconciliations between net loss attributable to Barnwell stockholders and common shares outstanding of the basic and diluted net loss per share computations are detailed in the following tables: Three months ended December 31, 2018 Net Loss (Numerator) Shares (Denominator) Per-Share Amount Basic net loss per share $ (4,600,000 ) 8,277,160 $ (0.56 ) Effect of dilutive securities - common stock options — — Diluted net loss per share $ (4,600,000 ) 8,277,160 $ (0.56 ) Three months ended December 31, 2017 Net Loss (Numerator) Shares (Denominator) Per-Share Amount Basic net loss per share $ (1,017,000 ) 8,277,160 $ (0.12 ) Effect of dilutive securities - common stock options — — Diluted net loss per share $ (1,017,000 ) 8,277,160 $ (0.12 ) |
INVESTMENTS (Tables)
INVESTMENTS (Tables) | 3 Months Ended |
Dec. 31, 2018 | |
Investments, All Other Investments [Abstract] | |
Summary of investments | A summary of Barnwell’s non-current investments is as follows: December 31, 2018 September 30, 2018 Investment in Kukio Resort Land Development Partnerships $ 1,127,000 $ 1,558,000 Investment in leasehold land interest – Lot 4C 50,000 50,000 Total non-current investments $ 1,177,000 $ 1,608,000 |
Summarized financial information for the land development partnerships | Summarized financial information for the Kukio Resort Land Development partnerships is as follows: Three months ended 2018 2017 Revenue $ 1,948,000 $ 1,560,000 Gross profit $ 646,000 $ 686,000 Net loss $ (158,000 ) $ (503,000 ) |
Summary of increment I and increment II percentage of sales payment revenues received | The following table summarizes Increment I and Increment II revenues from KD I and KD II and the amount of fees directly related to such revenues: Three months ended 2018 2017 Sale of interest in leasehold land: Revenues - sale of interest in leasehold land $ 165,000 $ — Fees - included in general and administrative expenses (20,000 ) — Sale of interest in leasehold land, net of fees $ 145,000 $ — |
RETIREMENT PLANS (Tables)
RETIREMENT PLANS (Tables) | 3 Months Ended |
Dec. 31, 2018 | |
Retirement Benefits [Abstract] | |
Schedule of components of net periodic benefit cost | The following table details the components of net periodic benefit (income) cost for Barnwell’s retirement plans: Pension Plan SERP Postretirement Medical Three months ended December 31, 2018 2017 2018 2017 2018 2017 Service cost $ 50,000 $ 53,000 $ 9,000 $ 6,000 $ — $ — Interest cost 93,000 89,000 21,000 15,000 25,000 19,000 Expected return on plan assets (161,000 ) (147,000 ) — — — — Amortization of prior service cost (credit) 1,000 1,000 (1,000 ) (1,000 ) — — Amortization of net actuarial loss 3,000 21,000 1,000 — 13,000 3,000 Net periodic benefit (income) cost $ (14,000 ) $ 17,000 $ 30,000 $ 20,000 $ 38,000 $ 22,000 |
INCOME TAXES (Tables)
INCOME TAXES (Tables) | 3 Months Ended |
Dec. 31, 2018 | |
Income Tax Disclosure [Abstract] | |
Components of loss before income taxes, after adjusting the earnings (loss) for non-controlling interests | The components of loss before income taxes, after adjusting the loss for non-controlling interests, are as follows Three months ended 2018 2017 United States $ (1,124,000 ) $ (1,143,000 ) Canada (3,581,000 ) (377,000 ) $ (4,705,000 ) $ (1,520,000 ) |
Schedule of components of the income tax provision (benefit) | The components of the income tax benefit are as follows: Three months ended 2018 2017 Current $ (33,000 ) $ (573,000 ) Deferred (72,000 ) 70,000 $ (105,000 ) $ (503,000 ) |
REVENUE FROM CONTRACTS WITH C_2
REVENUE FROM CONTRACTS WITH CUSTOMERS REVENUE FROM CONTRACTS WITH CUSTOMERS (Tables) | 3 Months Ended |
Dec. 31, 2018 | |
Revenue from Contract with Customer [Abstract] | |
Summary of impact of adoption to our condensed consolidated statements of operations and balance sheets | October 1, 2018 Pre-606 Balances 606 Adjustments Adjusted Balances ASSETS Current assets: Accounts and other receivables, net of allowance for doubtful accounts $ 1,965,000 $ (308,000 ) $ 1,657,000 Other current assets 950,000 687,000 1,637,000 LIABILITIES AND EQUITY Current liabilities: Other current liabilities 54,000 359,000 413,000 Equity: Retained earnings 13,253,000 20,000 13,273,000 In accordance with Topic 606, the disclosure of the impact of adoption to the Company’s Condensed Consolidated Statements of Operations and Condensed Consolidated Balance Sheets was as shown below. There were no impacts to the oil and natural gas or land investment segments. Three months ended December 31, 2018 Impact of changes in accounting policies As Reported Balances without adoption of Topic 606 Effect of change increase (decrease) Revenues: Contract drilling $ 1,163,000 $ 741,000 $ 422,000 Costs and expenses: Contract drilling operating 1,316,000 893,000 423,000 Loss before equity in loss of affiliates and income taxes (4,599,000 ) (4,598,000 ) (1,000 ) Loss before income taxes (4,678,000 ) (4,677,000 ) (1,000 ) Net loss (4,573,000 ) (4,572,000 ) (1,000 ) Less: Net earnings attributable to non-controlling interests 27,000 27,000 — Net loss attributable to Barnwell Industries, Inc. stockholders $ (4,600,000 ) $ (4,599,000 ) $ (1,000 ) Basic and diluted net loss per common share attributable to Barnwell Industries, Inc. stockholders $ (0.56 ) $ (0.56 ) $ — December 31, 2018 Impact of changes in accounting policies As Reported Balances without adoption of Topic 606 Effect of change increase (decrease) ASSETS Current assets: Accounts and other receivables, net of allowance for doubtful accounts $ 1,465,000 $ 1,819,000 $ (354,000 ) Other current assets 1,765,000 1,031,000 734,000 LIABILITIES AND EQUITY Current liabilities: Other current liabilities 452,000 91,000 361,000 Equity: Retained earnings 8,673,000 8,654,000 19,000 |
Summary of disaggregation of revenue | The following table provides information about disaggregated revenue by revenue streams, reportable segments, geographical region, and timing of revenue recognition for the three months ended December 31, 2018. Three months ended December 31, 2018 Oil and natural gas Contract drilling Land investment Other Total Revenue streams: Oil $ 896,000 $ — $ — $ — $ 896,000 Natural gas 162,000 — — — 162,000 Natural gas liquids 174,000 — — — 174,000 Drilling and pump — 1,163,000 — — 1,163,000 Contingent residual payments — — 165,000 — 165,000 Other — — — 14,000 14,000 Total revenues before interest income $ 1,232,000 $ 1,163,000 $ 165,000 $ 14,000 $ 2,574,000 Geographical regions: United States $ — $ 1,163,000 $ 165,000 $ — $ 1,328,000 Canada 1,232,000 — — 14,000 1,246,000 Total revenues before interest income $ 1,232,000 $ 1,163,000 $ 165,000 $ 14,000 $ 2,574,000 Timing of revenue recognition: Goods transferred at a point in time $ 1,232,000 $ — $ 165,000 $ 14,000 $ 1,411,000 Services transferred over time — 1,163,000 — — 1,163,000 Total revenues before interest income $ 1,232,000 $ 1,163,000 $ 165,000 $ 14,000 $ 2,574,000 |
Summary of contract with customer, asset and liability | The following table provides information about accounts receivables, contract assets and contract liabilities from contracts with customers: October 1, 2018 December 31, 2018 Accounts receivables from contracts with customers $ 1,245,000 $ 1,074,000 Contract assets 267,000 405,000 Contract liabilities 400,000 441,000 |
SEGMENT INFORMATION (Tables)
SEGMENT INFORMATION (Tables) | 3 Months Ended |
Dec. 31, 2018 | |
Segment Reporting [Abstract] | |
Schedule of financial information related to reporting segments | The following table presents certain financial information related to Barnwell’s reporting segments. All revenues reported are from external customers with no intersegment sales or transfers. Three months ended 2018 2017 Revenues: Oil and natural gas $ 1,232,000 $ 953,000 Contract drilling 1,163,000 842,000 Land investment 165,000 — Other 14,000 28,000 Total before interest income 2,574,000 1,823,000 Interest income 21,000 33,000 Total revenues $ 2,595,000 $ 1,856,000 Depletion, depreciation, and amortization: Oil and natural gas $ 749,000 $ 199,000 Contract drilling 57,000 61,000 Other 13,000 20,000 Total depletion, depreciation, and amortization $ 819,000 $ 280,000 Impairment: Oil and natural gas $ 2,170,000 $ — Total impairment $ 2,170,000 $ — Operating (loss) profit (before general and administrative expenses): Oil and natural gas $ (3,024,000 ) $ 96,000 Land investment 165,000 — Contract drilling (210,000 ) (40,000 ) Other 1,000 8,000 Total operating (loss) profit (3,068,000 ) 64,000 Equity in loss of affiliates: Land investment (79,000 ) (153,000 ) General and administrative expenses (1,548,000 ) (1,481,000 ) Interest expense (4,000 ) — Interest income 21,000 33,000 Loss before income taxes $ (4,678,000 ) $ (1,537,000 ) |
ACCUMULATED OTHER COMPREHENSI_2
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Tables) | 3 Months Ended |
Dec. 31, 2018 | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] | |
Schedule of changes in each component of accumulated other comprehensive (loss) income | The changes in each component of accumulated other comprehensive loss were as follows: Three months ended 2018 2017 Foreign currency translation: Beginning accumulated foreign currency translation $ 925,000 $ 1,053,000 Change in cumulative translation adjustment before reclassifications (413,000 ) (6,000 ) Income taxes — — Net current period other comprehensive loss (413,000 ) (6,000 ) Ending accumulated foreign currency translation 512,000 1,047,000 Retirement plans: Beginning accumulated retirement plans benefit cost (1,439,000 ) (2,111,000 ) Amortization of net actuarial loss and prior service cost 17,000 24,000 Income taxes — — Net current period other comprehensive income 17,000 24,000 Ending accumulated retirement plans benefit cost (1,422,000 ) (2,087,000 ) Accumulated other comprehensive loss, net of taxes $ (910,000 ) $ (1,040,000 ) |
INFORMATION RELATING TO THE C_2
INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Tables) | 3 Months Ended |
Dec. 31, 2018 | |
Supplemental Cash Flow Elements [Abstract] | |
Schedule of supplemental cash flow information | Three months ended 2018 2017 Supplemental disclosure of cash flow information: Cash paid (received) during the year for: Income taxes received $ (866,000 ) $ — Supplemental disclosure of non-cash investing activities: Canadian income tax withholding on proceeds from the sale of oil and natural gas properties $ — $ 37,000 |
SUMMARY OF SIGNIFICANT ACCOUN_3
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) | 3 Months Ended |
Dec. 31, 2018segment | |
Principles of Consolidation | |
Number of operating segments | 3 |
Kaupulehu Developments | |
Principles of Consolidation | |
Ownership interest in subsidiaries (as a percent) | 77.60% |
KD Kona 2013 LLLP | |
Principles of Consolidation | |
Ownership interest in subsidiaries (as a percent) | 75.00% |
Kaupulehu 2007, LLLP | |
Principles of Consolidation | |
Ownership interest in subsidiaries (as a percent) | 80.00% |
LOSS PER COMMON SHARE (Details)
LOSS PER COMMON SHARE (Details) - USD ($) $ / shares in Units, $ in Thousands | 3 Months Ended | |
Dec. 31, 2018 | Dec. 31, 2017 | |
Net Loss (Numerator) | ||
Basic | $ (4,600) | $ (1,017) |
Effect of dilutive securities - common stock options | 0 | 0 |
Diluted | $ (4,600) | $ (1,017) |
Shares (Denominator) | ||
Basic (in shares) | 8,277,160 | 8,277,160 |
Effect of dilutive securities - common stock options | 0 | 0 |
Diluted (in shares) | 8,277,160 | 8,277,160 |
Per-Share Amount | ||
Basic net loss per share (in dollars per share) | $ (0.56) | $ (0.12) |
Diluted net loss per share (in dollars per share) | $ (0.56) | $ (0.12) |
Options | ||
Antidilutive shares of common stock excluded from the computation of diluted shares | ||
Antidilutive shares excluded from computation of earnings (loss) per share (in shares) | 318,750 | 493,750 |
INVESTMENTS (Details)
INVESTMENTS (Details) | Dec. 31, 2018USD ($)alot | Nov. 27, 2013USD ($)partnership | Dec. 31, 2018USD ($)alot | Dec. 31, 2017USD ($) | Sep. 30, 2017a | Sep. 30, 2016 | Sep. 30, 2018USD ($) |
Investment in Land [Line Items] | |||||||
Investments | $ 1,177,000 | $ 1,177,000 | $ 1,608,000 | ||||
Equity in loss of affiliates | $ (79,000) | $ (153,000) | |||||
Percent of Increment II distributions | 50.00% | ||||||
Contingent payments, unrecorded | 8,000,000 | $ 8,000,000 | |||||
50% of Increment II distributions received | $ 3,500,000 | ||||||
Kaupulehu Developments | |||||||
Investment in Land [Line Items] | |||||||
Revenues - sale of interest in leasehold land | 165,000 | 0 | |||||
Fees - included in general and administrative expenses | (20,000) | 0 | |||||
Sale of interest in leasehold land, net of fees | $ 145,000 | 0 | |||||
Kaupulehu Developments | Minimum | |||||||
Investment in Land [Line Items] | |||||||
Third party fees, percentage | 10.40% | ||||||
Kaupulehu Developments | Maximum | |||||||
Investment in Land [Line Items] | |||||||
Third party fees, percentage | 11.60% | ||||||
KD Kaupulehu LLLP Increment I | Kaupulehu Developments | |||||||
Investment in Land [Line Items] | |||||||
Number of lots remaining to be sold | lot | 19 | 19 | |||||
Aggregate gross proceeds from sale of increment I single family lots for calculating payments entitled to be received | $ 216,400,000 | ||||||
Number of lots sold | lot | 1 | ||||||
Number of lots developed | lot | 80 | ||||||
KD Kaupulehu LLLP Increment I | Kaupulehu Developments | Aggregate gross proceeds greater than $100,000,000 up to $300,000,000 | |||||||
Investment in Land [Line Items] | |||||||
Payments entitled to be received as percentage of gross proceeds from sale of single family lots | 10.00% | ||||||
KD Kaupulehu LLLP Increment I | Kaupulehu Developments | Aggregate gross proceeds in excess of $300,000 | |||||||
Investment in Land [Line Items] | |||||||
Payments entitled to be received as percentage of gross proceeds from sale of single family lots | 14.00% | ||||||
KD Kaupulehu LLLP Increment I | Kaupulehu Developments | Minimum | Aggregate gross proceeds greater than $100,000,000 up to $300,000,000 | |||||||
Investment in Land [Line Items] | |||||||
Aggregate gross proceeds from sale of increment I single family lots for calculating payments entitled to be received | $ 100,000,000 | ||||||
KD Kaupulehu LLLP Increment I | Kaupulehu Developments | Minimum | Aggregate gross proceeds in excess of $300,000 | |||||||
Investment in Land [Line Items] | |||||||
Aggregate gross proceeds from sale of increment I single family lots for calculating payments entitled to be received | 300,000,000 | ||||||
KD Kaupulehu LLLP Increment I | Kaupulehu Developments | Maximum | Aggregate gross proceeds greater than $100,000,000 up to $300,000,000 | |||||||
Investment in Land [Line Items] | |||||||
Aggregate gross proceeds from sale of increment I single family lots for calculating payments entitled to be received | $ 300,000,000 | ||||||
KD Kaupulehu LLLP Increment II | Kaupulehu Developments | |||||||
Investment in Land [Line Items] | |||||||
Number of lots sold | 1 | 1 | |||||
Number of lots developed | 2 | ||||||
Percent of Increment II distributions | 50.00% | ||||||
Contingent payments, unrecorded | $ 8,000,000 | $ 8,000,000 | |||||
50% of Increment II distributions received | 3,500,000 | ||||||
KD Kaupulehu LLLP Increment II | Kaupulehu Developments | Minimum | |||||||
Investment in Land [Line Items] | |||||||
Payments entitled to be received as percentage of gross proceeds from sale of single family lots | 8.00% | ||||||
Payments entitled to be received as percentage of gross proceeds from sale of units on a lot | 2.60% | ||||||
Increment II lot size | a | 2 | ||||||
KD Kaupulehu LLLP Increment II | Kaupulehu Developments | Maximum | |||||||
Investment in Land [Line Items] | |||||||
Payments entitled to be received as percentage of gross proceeds from sale of single family lots | 10.00% | ||||||
Payments entitled to be received as percentage of gross proceeds from sale of units on a lot | 3.25% | ||||||
Increment II lot size | a | 3 | ||||||
KKM Makai LLP | Barnwell Hawaiian Properties, Inc. | |||||||
Investment in Land [Line Items] | |||||||
Preferred return to be received as a percentage from KKM | 100.00% | ||||||
KKM Makai LLP | Barnwell Hawaiian Properties, Inc. | Maximum | |||||||
Investment in Land [Line Items] | |||||||
Preferred return, amount from KKM | $ 1,000,000 | ||||||
Investment in land development partnerships | |||||||
Investment in Land [Line Items] | |||||||
Investments | $ 1,127,000 | $ 1,127,000 | 1,558,000 | ||||
Number of limited liability limited partnerships formed | partnership | 2 | ||||||
Ownership percentage | 19.60% | ||||||
Number of lots remaining to be sold | lot | 19 | 19 | |||||
Cash distribution from equity method investment | $ 314,000 | 0 | |||||
Minority interests portion of distribution from equity investee | 38,000 | ||||||
Cumulative cash distributions from Kukio Resort Land Development Partnerships, made to date | 45,000,000 | ||||||
Equity in loss of affiliates | (79,000) | (153,000) | |||||
Basis difference between the underlying equity in net assets of the investee and the carrying value of the entity's investment | $ 313,000 | 313,000 | |||||
Basis difference adjustment | 1,000 | 3,000 | |||||
Summarized financial information | |||||||
Revenue | 1,948,000 | 1,560,000 | |||||
Gross profit | 646,000 | 686,000 | |||||
Net earnings | $ (158,000) | $ (503,000) | |||||
Investment in land development partnerships | Minimum | |||||||
Investment in Land [Line Items] | |||||||
Cumulative cash distributions from Kukio Resort Land Development Partnerships, threshold (in excess of) | $ 45,000,000 | ||||||
Investment in land development partnerships | KD Kukio Resorts, LLLP, KD Maniniowali, LLLP, and KD Kaupulehu, LLLP | |||||||
Investment in Land [Line Items] | |||||||
Ownership interest acquired, aggregate cost | $ 5,140,000 | ||||||
Investment in land development partnerships | KD Kukio Resorts LLLP | |||||||
Investment in Land [Line Items] | |||||||
Ownership interest acquired (as a percent) | 19.60% | ||||||
Investment in land development partnerships | KD Maniniowali, LLLP | |||||||
Investment in Land [Line Items] | |||||||
Ownership interest acquired (as a percent) | 19.60% | ||||||
Investment in land development partnerships | KD Kaupulehu, LLLP | |||||||
Investment in Land [Line Items] | |||||||
Ownership interest acquired (as a percent) | 19.60% | ||||||
Investment in land development partnerships | KD Kaupulehu LLLP Increment II Phase 2A | |||||||
Investment in Land [Line Items] | |||||||
Number of single family lots, rights to | 3 | 3 | |||||
Investment in land development partnerships | KKM Makai LLP | |||||||
Investment in Land [Line Items] | |||||||
Ownership interest acquired (as a percent) | 34.45% | ||||||
Land in leasehold land interest - Lot 4C | |||||||
Investment in Land [Line Items] | |||||||
Investments | $ 50,000 | $ 50,000 | $ 50,000 | ||||
Area of land (in acres) | a | 1,000 | 1,000 |
OIL AND NATURAL GAS PROPERTIES
OIL AND NATURAL GAS PROPERTIES (Details) - USD ($) $ in Thousands | 1 Months Ended | 3 Months Ended | ||
Oct. 31, 2017 | Dec. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2018 | |
Oil and Natural Gas Properties [Line Items] | ||||
Proceeds from sale of oil and natural gas assets | $ 633 | $ 35 | ||
Income taxes receivable | 1,503 | $ 2,461 | ||
Impairment of assets | 2,170 | 0 | ||
Pouce Coupe | ||||
Oil and Natural Gas Properties [Line Items] | ||||
Proceeds from sale of oil and natural gas assets | $ 72 | |||
Income taxes receivable | $ 37 | |||
Wood River and Twining | ||||
Oil and Natural Gas Properties [Line Items] | ||||
Acquisition costs | $ 355 |
RETIREMENT PLANS (Details)
RETIREMENT PLANS (Details) - USD ($) $ in Thousands | 3 Months Ended | |
Dec. 31, 2018 | Dec. 31, 2017 | |
Pension Plan | ||
Net periodic benefit cost: | ||
Service cost | $ 50 | $ 53 |
Interest cost | 93 | 89 |
Expected return on plan assets | (161) | (147) |
Amortization of prior service cost (credit) | 1 | 1 |
Amortization of net actuarial loss | 3 | 21 |
Net periodic benefit (income) cost | (14) | 17 |
Other disclosures | ||
Estimated future Pension Plan contributions | 150 | |
SERP | ||
Net periodic benefit cost: | ||
Service cost | 9 | 6 |
Interest cost | 21 | 15 |
Amortization of prior service cost (credit) | (1) | (1) |
Amortization of net actuarial loss | 1 | 0 |
Net periodic benefit (income) cost | 30 | 20 |
Postretirement Medical | ||
Net periodic benefit cost: | ||
Service cost | 0 | 0 |
Interest cost | 25 | 19 |
Amortization of prior service cost (credit) | 0 | 0 |
Amortization of net actuarial loss | 13 | 3 |
Net periodic benefit (income) cost | $ 38 | $ 22 |
INCOME TAXES (Details)
INCOME TAXES (Details) - USD ($) $ in Thousands | 3 Months Ended | |
Dec. 31, 2018 | Dec. 31, 2017 | |
Components of loss before income taxes, after adjusting the earnings (loss) for non-controlling interests | ||
United States | $ (1,124) | $ (1,143) |
Canada | (3,581) | (377) |
Total | (4,705) | (1,520) |
Components of the income tax provision (benefit) | ||
Current | (33) | (573) |
Deferred | (72) | 70 |
Total | $ (105) | (503) |
Income tax benefit from AMT credit carryover refund provision | $ (460) |
REVENUE FROM CONTRACTS WITH C_3
REVENUE FROM CONTRACTS WITH CUSTOMERS REVENUE FROM CONTRACTS WITH CUSTOMERS - IMPACT OF ADOPTION (Details) - USD ($) $ / shares in Units, $ in Thousands | 3 Months Ended | |||
Dec. 31, 2018 | Dec. 31, 2017 | Oct. 01, 2018 | Sep. 30, 2018 | |
Statement of Financial Position [Abstract] | ||||
Accounts and other receivables, net of allowance for doubtful accounts | $ 1,465 | $ 1,657 | $ 1,965 | |
Other current assets | 1,765 | 1,637 | 950 | |
Other current liabilities | 452 | 413 | 54 | |
Retained earnings | 8,673 | 13,273 | $ 13,253 | |
Income Statement [Abstract] | ||||
Contract drilling revenue | 1,163 | |||
Contract drilling operating expense | 1,316 | $ 821 | ||
Loss before equity in loss of affiliates and income taxes | (4,599) | (1,384) | ||
Loss before income taxes | (4,678) | (1,537) | ||
Net loss | (4,573) | (1,034) | ||
Less: Net earnings attributable to non-controlling interests | 27 | (17) | ||
Net loss attributable to Barnwell Industries, Inc. stockholders | $ (4,600) | $ (1,017) | ||
Basic and diluted net loss per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share) | $ (0.56) | $ (0.12) | ||
Calculated under revenue guidance in effect before Topic 606 | Accounting Standards Update 2014-09 | ||||
Statement of Financial Position [Abstract] | ||||
Accounts and other receivables, net of allowance for doubtful accounts | $ 1,819 | 1,965 | ||
Other current assets | 1,031 | 950 | ||
Other current liabilities | 91 | 54 | ||
Retained earnings | 8,654 | 13,253 | ||
Income Statement [Abstract] | ||||
Contract drilling revenue | 741 | |||
Contract drilling operating expense | 893 | |||
Loss before equity in loss of affiliates and income taxes | (4,598) | |||
Loss before income taxes | (4,677) | |||
Net loss | (4,572) | |||
Less: Net earnings attributable to non-controlling interests | 27 | |||
Net loss attributable to Barnwell Industries, Inc. stockholders | $ (4,599) | |||
Basic and diluted net loss per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share) | $ (0.56) | |||
Difference between revenue guidance in effect before and after Topic 606 | Accounting Standards Update 2014-09 | ||||
Statement of Financial Position [Abstract] | ||||
Accounts and other receivables, net of allowance for doubtful accounts | $ (354) | (308) | ||
Other current assets | 734 | 687 | ||
Other current liabilities | 361 | 359 | ||
Retained earnings | 19 | $ 20 | ||
Income Statement [Abstract] | ||||
Contract drilling revenue | 422 | |||
Contract drilling operating expense | 423 | |||
Loss before equity in loss of affiliates and income taxes | (1) | |||
Loss before income taxes | (1) | |||
Net loss | (1) | |||
Less: Net earnings attributable to non-controlling interests | 0 | |||
Net loss attributable to Barnwell Industries, Inc. stockholders | $ (1) | |||
Basic and diluted net loss per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share) | $ 0 |
REVENUE FROM CONTRACTS WITH C_4
REVENUE FROM CONTRACTS WITH CUSTOMERS REVENUE FROM CONTRACTS WITH CUSTOMERS - DISAGGREGATION OF REVENUE (Details) - USD ($) $ in Thousands | 3 Months Ended | |
Dec. 31, 2018 | Dec. 31, 2017 | |
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | $ 2,574 | $ 1,823 |
Oil | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 896 | |
Natural gas | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 162 | |
Natural gas liquids | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 174 | |
Drilling and pump | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 1,163 | |
Contingent residual payments | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 165 | |
Other | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 14 | |
United States | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 1,328 | |
Canada | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 1,246 | |
Goods transferred at a point in time | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 1,411 | |
Services transferred over time | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 1,163 | |
Oil and natural gas | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 1,232 | 953 |
Oil and natural gas | Oil | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 896 | |
Oil and natural gas | Natural gas | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 162 | |
Oil and natural gas | Natural gas liquids | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 174 | |
Oil and natural gas | Drilling and pump | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Oil and natural gas | Contingent residual payments | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Oil and natural gas | Other | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Oil and natural gas | United States | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Oil and natural gas | Canada | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 1,232 | |
Oil and natural gas | Goods transferred at a point in time | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 1,232 | |
Oil and natural gas | Services transferred over time | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Contract drilling | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 1,163 | 842 |
Contract drilling | Oil | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Contract drilling | Natural gas | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Contract drilling | Natural gas liquids | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Contract drilling | Drilling and pump | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 1,163 | |
Contract drilling | Contingent residual payments | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Contract drilling | Other | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Contract drilling | United States | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 1,163 | |
Contract drilling | Canada | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Contract drilling | Goods transferred at a point in time | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Contract drilling | Services transferred over time | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 1,163 | |
Land investment | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 165 | 0 |
Land investment | Oil | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Land investment | Natural gas | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Land investment | Natural gas liquids | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Land investment | Drilling and pump | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Land investment | Contingent residual payments | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 165 | |
Land investment | Other | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Land investment | United States | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 165 | |
Land investment | Canada | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Land investment | Goods transferred at a point in time | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 165 | |
Land investment | Services transferred over time | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Other | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 14 | $ 28 |
Other | Oil | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Other | Natural gas | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Other | Natural gas liquids | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Other | Drilling and pump | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Other | Contingent residual payments | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Other | Other | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 14 | |
Other | United States | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 0 | |
Other | Canada | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 14 | |
Other | Goods transferred at a point in time | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | 14 | |
Other | Services transferred over time | ||
Disaggregation of Revenue [Line Items] | ||
Revenue before interest income | $ 0 |
REVENUE FROM CONTRACTS WITH C_5
REVENUE FROM CONTRACTS WITH CUSTOMERS REVENUE FROM CONTRACTS WITH CUSTOMERS - CONTRACT BALANCES (Details) - USD ($) $ in Thousands | Dec. 31, 2018 | Oct. 01, 2018 |
Revenue from Contract with Customer [Abstract] | ||
Accounts receivables from contracts with customers | $ 1,074 | $ 1,245 |
Contract assets | 405 | 267 |
Contract liabilities | $ 441 | $ 400 |
REVENUE FROM CONTRACTS WITH C_6
REVENUE FROM CONTRACTS WITH CUSTOMERS REVENUE FROM CONTRACTS WITH CUSTOMERS - NARRATIVE (Details) $ in Thousands | 3 Months Ended |
Dec. 31, 2018USD ($) | |
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |
Contract with customer, liability, current | $ 441 |
Contract with customer, liability, revenue recognized | 21 |
Revenue, remaining performance obligation (backlog) | $ 5,738 |
Percentage anticipated to be recognized in next 12 months | 66.00% |
Capitalized contract cost net, preconstruction | $ 88 |
Minimum | |
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |
Contract receivable retainage percentage | 5.00% |
Maximum | |
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |
Contract receivable retainage percentage | 10.00% |
SEGMENT INFORMATION (Details)
SEGMENT INFORMATION (Details) - USD ($) | 3 Months Ended | |
Dec. 31, 2018 | Dec. 31, 2017 | |
Revenues: | ||
Revenue from contract with customer | $ 2,574,000 | $ 1,823,000 |
Interest income | 21,000 | 33,000 |
Total revenues | 2,595,000 | 1,856,000 |
Depletion, depreciation, and amortization: | ||
Depletion, depreciation, and amortization | 819,000 | 280,000 |
Asset Impairment Charges [Abstract] | ||
Impairment of assets | 2,170,000 | 0 |
Operating (loss) profit (before general and administrative expenses): | ||
Operating (loss) profit (before general and administrative expenses): | (3,068,000) | 64,000 |
Equity in income (loss) of affiliates: | ||
Equity in loss of affiliates | (79,000) | (153,000) |
General and administrative expenses | (1,548,000) | (1,481,000) |
Interest expense | (4,000) | 0 |
Interest income | 21,000 | 33,000 |
Loss before income taxes | (4,678,000) | (1,537,000) |
Oil and natural gas | ||
Revenues: | ||
Revenue from contract with customer | 1,232,000 | 953,000 |
Total revenues | 1,232,000 | 953,000 |
Depletion, depreciation, and amortization: | ||
Depletion, depreciation, and amortization | 749,000 | 199,000 |
Asset Impairment Charges [Abstract] | ||
Impairment of assets | 2,170,000 | 0 |
Operating (loss) profit (before general and administrative expenses): | ||
Operating (loss) profit (before general and administrative expenses): | (3,024,000) | 96,000 |
Contract drilling | ||
Revenues: | ||
Revenue from contract with customer | 1,163,000 | 842,000 |
Total revenues | 1,163,000 | 842,000 |
Depletion, depreciation, and amortization: | ||
Depletion, depreciation, and amortization | 57,000 | 61,000 |
Operating (loss) profit (before general and administrative expenses): | ||
Operating (loss) profit (before general and administrative expenses): | (210,000) | (40,000) |
Land investment | ||
Revenues: | ||
Revenue from contract with customer | 165,000 | 0 |
Total revenues | 165,000 | 0 |
Operating (loss) profit (before general and administrative expenses): | ||
Operating (loss) profit (before general and administrative expenses): | 165,000 | 0 |
Other | ||
Revenues: | ||
Revenue from contract with customer | 14,000 | 28,000 |
Total revenues | 35,000 | 61,000 |
Depletion, depreciation, and amortization: | ||
Depletion, depreciation, and amortization | 13,000 | 20,000 |
Operating (loss) profit (before general and administrative expenses): | ||
Operating (loss) profit (before general and administrative expenses): | 1,000 | $ 8,000 |
Intersegment eliminations | ||
Revenues: | ||
Total revenues | $ 0 |
ACCUMULATED OTHER COMPREHENSI_3
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Details) - USD ($) $ in Thousands | 3 Months Ended | ||
Dec. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2018 | |
Changes in foreign currency translation | |||
Beginning accumulated foreign currency translation | $ 925 | $ 1,053 | |
Change in cumulative translation adjustment before reclassifications | (413) | (6) | |
Income taxes | 0 | 0 | |
Net current period other comprehensive loss | (413) | (6) | |
Ending accumulated foreign currency translation | 512 | 1,047 | |
Changes in retirement plans | |||
Beginning accumulated retirement plans benefit cost | (1,439) | (2,111) | |
Amortization of net actuarial loss and prior service cost | 17 | 24 | |
Income taxes | 0 | 0 | |
Net current period other comprehensive income | 17 | 24 | |
Ending accumulated retirement plans benefit cost | (1,422) | (2,087) | |
Accumulated other comprehensive loss, net of taxes | $ (910) | $ (1,040) | $ (514) |
INFORMATION RELATING TO THE C_3
INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Details) - USD ($) $ in Thousands | 3 Months Ended | |
Dec. 31, 2018 | Dec. 31, 2017 | |
Supplemental disclosure of cash flow information: | ||
Income taxes received | $ (866) | $ 0 |
Supplemental disclosure of non-cash investing activities: | ||
Canadian income tax withholding on proceeds from the sale of oil and natural gas properties | 0 | 37 |
Oil and natural gas | ||
Supplemental disclosures of cash flow information: | ||
(Decrease) increase in capital expenditure accruals related to oil and natural gas exploration and development | (66) | 30 |
Increase (decrease) in capital expenditure accruals related to oil and natural gas asset retirement obligations | $ 146 | $ (30) |
RELATED PARTY TRANSACTIONS (Det
RELATED PARTY TRANSACTIONS (Details) $ in Thousands | Dec. 31, 2018USD ($) | Dec. 31, 2018USD ($)lot | Dec. 31, 2017USD ($)lot |
Related party transactions | |||
Percent of Increment II distributions | 50.00% | ||
Contingent payments, unrecorded | $ 8,000 | $ 8,000 | |
50% of Increment II distributions received | $ 3,500 | ||
Kaupulehu Developments | |||
Related party transactions | |||
Sale of interest in leasehold land | $ 165 | $ 0 | |
Kaupulehu Developments | KD Kaupulehu, LLLP | Investment in land development partnerships | |||
Related party transactions | |||
Ownership interest acquired (as a percent) | 19.60% | 19.60% | |
Sale of interest in leasehold land | $ 165 | ||
Increment II [Member] | Kaupulehu Developments | KD Kaupulehu, LLLP | Investment in land development partnerships | |||
Related party transactions | |||
Number of lots sold | lot | 1 | 0 |