isramco20190630

10-Q 1 isramco20190630_10q.htm FORM 10-Q isramco20190630_10q.htm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

Check One
☒	Quarterly report under Section 13 or 15(d) of the Securities Exchange Act of 1934 for the quarterly period ended June 30, 2019

	or

☐	Transition report under Section 13 or 15(d) of the Securities Exchange Act of 1934

Commission File Number 0-12500

ISRAMCO, INC

(Exact Name of registrant as Specified in its Charter)

Delaware		13-3145265
(State or other Jurisdiction of Incorporation or Organization)		I.R.S. Employer Number

1001 West Loop South, Suite 750, HOUSTON, TX 77027

(Address of Principal Executive Offices)

713-621-5946

(Registrant’s Telephone Number, Including Area Code)

Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock, $0.01 par value per share	ISRL	The Nasdaq Stock Market LLC

Indicate by check whether the registrant: (1) filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See definition of “large accelerated filer,” accelerated filer” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act:

Large accelerated filer ☐		Accelerated filer ☒

Non-accelerated filer ☐		Smaller Reporting Company ☒

Emerging growth company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

As of August 9, 2019, Isramco, Inc., had 2,717,648 outstanding shares of common stock, par value $0.01 per share.

TABLE OF CONTENTS

		Page
PART I. FINANCIAL INFORMATION

Item 1.	Consolidated Financial Statements (unaudited)	4
	Consolidated Balance Sheets at June 30, 2019 and December 31, 2018	4
	Consolidated Statements of Operations for the three and six months ended June 30, 2019 and 2018	5
	Consolidated Statements of Changes in Shareholders’ Deficit for the three and six months ended June 30, 2019 and 2018	6
	Consolidated Statements of Cash Flows for the six months ended June 30, 2019 and 2018	7
	Notes to Consolidated Financial Statements	8
Item 2.	Management’s discussion and analysis of Financial Condition and Results of Operations	22
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	36
Item 4.	Controls and Procedures	36

PART II. OTHER INFORMATION

Item 1.	Legal Proceedings	37
Item 1A.	Risk Factors	37
Item 2.	Changes in Securities and Use of Proceeds and Issuer Purchases of Equity Securities	37
Item 3.	Defaults Upon Senior Securities	37
Item 4	(Removed and Reserved)	37
Item 5.	Other Information	37
Item 6.	Exhibits	38
	Signatures	39

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Forward Looking Statements

CERTAIN STATEMENTS MADE IN THIS QUARTERLY REPORT ON FORM 10-Q ARE “FORWARD-LOOKING STATEMENTS” WITHIN THE MEANING OF THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995. FORWARD-LOOKING STATEMENTS CAN BE IDENTIFIED BY TERMINOLOGY SUCH AS “MAY”, “WILL”, “SHOULD”, “EXPECTS”, “INTENDS”, “ANTICIPATES”, “BELIEVES”, “ESTIMATES”, “PREDICTS”, OR “CONTINUE” OR THE NEGATIVE OF THESE TERMS OR OTHER COMPARABLE TERMINOLOGY AND INCLUDE, WITHOUT LIMITATION, STATEMENTS BELOW REGARDING EXPLORATION AND DRILLING PLANS, FUTURE GENERAL AND ADMINISTRATIVE EXPENSES, FUTURE GROWTH, FUTURE EXPLORATION, FUTURE GEOPHYSICAL AND GEOLOGICAL DATA, GENERATION OF ADDITIONAL PROPERTIES, RESERVES, NEW PROSPECTS AND DRILLING LOCATIONS, FUTURE CAPITAL EXPENDITURES, SUFFICIENCY OF WORKING CAPITAL, ABILITY TO RAISE ADDITIONAL CAPITAL, PROJECTED CASH FLOWS FROM OPERATIONS, OUTCOME OF ANY LEGAL PROCEEDINGS, DRILLING PLANS, THE NUMBER, TIMING OR RESULTS OF ANY WELLS, INTERPRETATION AND RESULTS OF SEISMIC SURVEYS OR SEISMIC DATA, FUTURE PRODUCTION OR RESERVES, LEASE OPTIONS OR RIGHTS, PARTICIPATION OF OPERATING PARTNERS, CONTINUED RECEIPT OF ROYALTIES, AND ANY OTHER STATEMENTS REGARDING FUTURE OPERATIONS, FINANCIAL RESULTS, OPPORTUNITIES, GROWTH, BUSINESS PLANS AND STRATEGY. BECAUSE FORWARD-LOOKING STATEMENTS INVOLVE RISKS AND UNCERTAINTIES, THERE ARE IMPORTANT FACTORS THAT COULD CAUSE ACTUAL RESULTS TO DIFFER MATERIALLY FROM THOSE EXPRESSED OR IMPLIED BY THESE FORWARD-LOOKING STATEMENTS. ALTHOUGH THE COMPANY BELIEVES THAT EXPECTATIONS REFLECTED IN THE FORWARD-LOOKING STATEMENTS ARE REASONABLE, IT CANNOT GUARANTEE FUTURE RESULTS, PERFORMANCE OR ACHIEVEMENTS. MOREOVER, NEITHER THE COMPANY NOR ANY OTHER PERSON ASSUMES RESPONSIBILITY FOR THE ACCURACY AND COMPLETENESS OF THESE FORWARD-LOOKING STATEMENTS. THE COMPANY IS UNDER NO DUTY TO UPDATE ANY FORWARD-LOOKING STATEMENTS AFTER THE DATE OF THIS REPORT TO CONFORM SUCH STATEMENTS TO ACTUAL RESULTS.

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PART I - Financial Information

ITEM 1. Financial Statements

ISRAMCO INC.

CONSOLIDATED BALANCE SHEETS

(In thousands, except share and per share amounts)

(Unaudited)

	As of June 30, 2019			As of December 31, 2018
ASSETS
Current Assets:
Cash and cash equivalents	$	12,742		$	13,857
Accounts receivable, net of allowances for doubtful accounts of $2,419 and $2,553		15,727			18,920
Restricted and designated cash		832			830
Inventories		605			563
Derivative asset		16			293
Prepaid expenses and other		1,733			2,956
Total Current Assets		31,655			37,419

Property and Equipment, at cost – successful efforts method:
Oil and Gas properties		244,666			244,450
Advanced payment for equipment		662			569
Production service equipment and other equipment and property		68,447			66,929
Total Property and Equipment		313,775			311,948
Accumulated depreciation, depletion, amortization and impairment		(260,492	)		(257,706	)
Net Property and Equipment		53,283			54,242

Derivative asset		-			388
Restricted cash – long term		21,543			19,304
Investments		261			261
Total Assets	$	106,742		$	111,614

LIABILITIES AND SHAREHOLDERS’ DEFICIT
Current Liabilities:
Accounts payable and accrued expenses	$	13,865		$	13,976
Short term debt and current maturities of long-term debt, net of discount of $632 and $724		19,548			21,739
Payables due to related party		4,573			3,836
Accrued interest		924			1,057
Total Current Liabilities		38,910			40,608

Long term debt, net of discount of $1,117 and $1,407		47,183			56,193

Other Long-term Liabilities:
Derivative liability		326			-
Asset retirement obligations		22,348			22,172
Total Liabilities		108,767			118,973

Commitments and contingencies

Shareholders’ Deficit:
Common stock $0.01 par value; authorized 7,500,000 shares; issued 2,746,915 shares; outstanding 2,717,648 shares		27			27
Additional paid-in capital		23,853			23,853
Accumulated deficit		(16,738	)		(23,036	)
Treasury stock, 29,267 shares at cost		(164	)		(164	)
Total Isramco, Inc. Shareholders’ Deficit		6,978			680
Non-controlling interest		(9,003	)		(8,039	)
Total Deficit		(2,025	)		(7,359	)
Total Liabilities and Shareholders’ Deficit	$	106,742		$	111,614

See notes to the unaudited consolidated financial statements.

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ISRAMCO INC.

CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except share and per share amounts)

(Unaudited)

	Three Months Ended June 30						Six Months Ended June 30
	2019			2018			2019			2018

Revenues and other
Oil and gas sales	$	10,538		$	11,783		$	21,856		$	22,767
Production services		7,816			7,927			17,248			13,690
Office services		134			131			265			267
Gain on divestiture		-			-			-			472
Other		134			151			269			289
Total revenues and other		18,622			19,992			39,638			37,485

Operating expenses
Lease operating expense, transportation and taxes		2,257			2,360			4,686			4,660
Depreciation, depletion and amortization		1,373			1,455			2,703			2,746
Accretion expense		219			228			434			458
Production services		7,820			7,360			16,334			12,945
Loss (gain) from plug and abandonment		(49	)		154			13			212
General and administrative		2,138			1,205			3,592			2,570
Total operating expenses		13,758			12,762			27,762			23,591
Operating income		4,864			7,230			11,876			13,894

Other expenses
Interest expense, net		933			1,333			2,117			2,550
Loss (gain) from derivative contracts, net		513			(283	)		846			(1,148	)
Capital loss		3			11			1			11
Total other expenses		1,449			1,061			2,964			1,413

Income before income taxes		3,415			6,169			8,912			12,481
Income tax expense		(1,705	)		(1,786	)		(3,568	)		(3,444	)

Net income	$	1,710		$	4,383		$	5,344		$	9,037
Net loss attributable to non-controlling interests		(557	)		(325	)		(954	)		(706	)
Net income attributable to Isramco	$	2,267		$	4,708		$	6,298		$	9,743

Earnings per share – basic:	$	0.83		$	1.73		$	2.32		$	3.59

Earnings per share – diluted:	$	0.83		$	1.73		$	2.32		$	3.59

Weighted average number of shares outstanding basic:		2,717,648			2,717,648			2,717,648			2,717,648
Weighted average number of shares outstanding diluted:		2,717,648			2,717,648			2,717,648			2,717,648

See notes to the unaudited consolidated financial statements.

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ISRAMCO INC.

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ DEFICIT

FOR THE THREE AND SIX MONTHS ENDED JUNE 30, 2019 AND 2018

(in thousands, except share amounts)

(Unaudited)

	Common stock
	Number of shares		Amount		Additional Paid-In Capital		Accumulated Deficit			Treasury stock			Non-controlling interests			Total Shareholders’ Deficit

Balance of December 31, 2018		2,717,648	$	27	$	23,853	$	(23,036	)	$	(164	)	$	(8,039	)	$	(7,359	)

Distribution to non-controlling interests														(10	)		(10	)

Net income (loss)								4,031						(397	)		3,634

Balance of March 31, 2019		2,717,648	$	27	$	23,853	$	(19,005	)	$	(164	)	$	(8,446	)	$	(3,735	)

Net income (loss)								2,267						(557	)		1,710

Balance of June 30, 2019		2,717,648	$	27	$	23,853	$	(16,738	)	$	(164	)	$	(9,003	)	$	(2,025	)

Balance of December 31, 2017		2,717,648	$	27	$	23,853	$	(40,970	)	$	(164	)	$	(6,564	)	$	(23,818	)

Net income (loss)								5,035						(381	)		4,654

Balance of March 31, 2018		2,717,648	$	27	$	23,853	$	(35,935	)	$	(164	)	$	(6,945	)	$	(19,164	)

Net income (loss)								4,708						(325	)		4,383

Balance of June 30, 2018		2,717,648	$	27	$	23,853	$	(31,227	)	$	(164	)	$	(7,270	)	$	(14,781	)

See notes to the unaudited consolidated financial statements.

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ISRAMCO INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)

	Six months Ended June 30,
	2019			2018

Cash Flows From Operating Activities:
Net income	$	5,344		$	9,037
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion, amortization and impairment		2,703			2,746
Bad debt expense		10			58
Accretion expense		434			458
Gain on divestiture		-			(472	)
Net unrealized (gain) loss on derivative contracts		991			(1,467	)
Loss on sale of equipment and other		1			11
Amortization of debt cost		382			411
Changes in components of working capital and other assets and liabilities
Accounts receivable		3,183			(6,746	)
Prepaid expenses, other receivables and other current assets		1,223			1,183
Due to related party		137			(10	)
Inventories		(42	)		54
Accounts payable and accrued expenses		(630	)		(104	)
Net cash provided by operating activities		13,736			5,159

Cash flows from investing activities:
Addition to property and equipment, net		(1,645	)		(4,919	)
Proceeds from sale of oil and gas properties and equipment		28			455
Net cash used in investing activities		(1,617	)		(4,464	)

Cash flows from financing activities:
Repayments of long term debt		(11,100	)		(7,800	)
Borrowings short-term debt – related parties		600			-
Bank overdraft, net		-			98
Distributions to non-controlling interests		(10	)		-
Repayments of short - term debt, net		(483	)		(343	)
Net cash used in financing activities		(10,993	)		(8,045	)

Net increase (decrease) in cash, cash equivalents, and restricted cash		1,126			(7,350	)
Cash, cash equivalents, and restricted cash at beginning of period		33,991			40,485
Cash, cash equivalents, and restricted cash at end of period	$	35,117		$	33,135

See notes to the unaudited consolidated financial statements.

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Isramco Inc.

Notes to Consolidated Financial Statements

(Unaudited)

Note 1 - Financial Statement Presentation

Isramco, Inc. and its subsidiaries and affiliated companies (together referred to as “We”, “Our”, “Isramco” or the “Company”) is predominately an independent oil and natural gas company engaged in the exploration, development and production of oil and natural gas properties located onshore in the United States and ownership of various royalty interests in oil and gas concessions located offshore Israel. The Company also operates a production services company that provides well maintenance and workover services, well completion, and recompletion services.

The accompanying unaudited financial statements and notes of Isramco have been prepared pursuant to the rules and regulations of the United States Securities and Exchange Commission (the “Commission”). Pursuant to such rules and regulations, certain disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been omitted. The accompanying financial statements and notes should be read in conjunction with the accompanying financial statements and notes included in Isramco’s Annual Report on Form 10-K for the year ended December 31, 2018.

The accompanying unaudited interim financial statements furnished in this report reflect all adjustments that are, in the opinion of management, necessary to fairly present Isramco’s results of operations and cash flows for the six-month periods ended June 30, 2019 and 2018 and Isramco’s financial position as of June 30, 2019.

Use of Estimates

In preparing financial statements in accordance with accounting principles generally accepted in the United States, management makes informed judgments and estimates that affect the reported amounts of assets, liabilities, revenues, and expenses. Management evaluates its estimates and related assumptions regularly, including those related to the value of properties and equipment; proved reserves; intangible assets; asset retirement obligations; litigation reserves; environmental liabilities; liabilities, and costs; income taxes; and fair values. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ from these estimates.

Consolidated interim period results are not necessarily indicative of results of operations or cash flows for the full year and accordingly, certain information normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States has been condensed or omitted. The Company has evaluated events or transactions through the date of issuance of these consolidated financial statements.

Concentrations of Credit Risk

Financial instruments, which potentially expose Isramco to concentrations of credit risk, consist primarily of interest rate swaps, cash equivalents, trade and joint interest accounts receivable. Isramco’s customer base includes several of the major United States oil and gas operating and production companies as well as major power companies in Israel. Although Isramco is directly affected by the well-being of the oil and gas production industry, management does not believe a significant credit risk existed as of June 30, 2019. Isramco continues to monitor and review credit exposure of its marketing counter-parties.

Tamar Royalties LLC, a wholly owned subsidiary of Isramco Inc., entered into certain swap and cap agreements with Deutsche Bank AG London Branch to hedge the risk of interest rate volatility. See Note 4 for details.

Our production services segment customers include major oil and natural gas production companies and independent oil and natural gas production companies. We perform ongoing credit evaluations of our customers and usually do not require material collateral. We maintain reserves for potential credit losses when necessary. Our results of operations and financial position should be considered in light of the fluctuations in demand experienced by oilfield service companies as changes in oil and gas producers’ expenditures and budgets occur. These fluctuations can impact our results of operations and financial position as supply and demand factors directly affect utilization and hours which are the primary determinants of our net cash provided by operating activities.

Isramco maintains deposits in banks, which may exceed the amount of federal deposit insurance available. Management periodically assesses the financial condition of the institutions and believes that any possible deposit loss is minimal.

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Risk Management Activities

The Company follows Accounting Standards Codification (ASC) 815, Derivatives and Hedging. From time to time, the Company may hedge a portion of its forecasted oil and natural gas production or may hedge interest rates on variable interest rate loans. Derivative contracts entered into by the Company have consisted of transactions in which the Company hedges the variability of cash flow related to a forecasted transaction. The Company has elected not to designate any of its positions for hedge accounting. Accordingly, the Company records the net change in the mark-to-market valuation of these positions, as well as payments and receipts on settled contracts, in “Net loss (gain) on derivative contracts” in the consolidated statements of operations. Currently, the Company has no derivative contracts in place to hedge against fluctuations in oil and natural gas prices.

Fair Value

Fair value accounting applies to reported balances that are required or permitted to be measured at fair value under existing accounting pronouncements. Fair value measurements are determined based on the assumptions that market participants would use in pricing the asset or liability. As a basis for considering market participant assumptions in fair value measurements, these accounting requirements establish a fair value hierarchy that distinguishes between market participant assumptions based on market data obtained from sources independent of the reporting entity (observable inputs that are classified within Levels 1 and 2 of the hierarchy) and the reporting entity’s own assumptions about market participant assumptions (unobservable inputs classified within Level 3 of the hierarchy).

Level 1 inputs utilize quoted prices (unadjusted) in active markets for identical assets or liabilities that we have the ability to access.

Level 2 inputs are inputs other than quoted prices included in Level 1 that are observable for the asset or liability, either directly or indirectly. Level 2 inputs might include quoted prices for similar assets and liabilities in active markets, as well as inputs that are observable for the asset or liability (other than quoted prices), such as interest rates, foreign exchange rates, and yield curves that are observable at commonly quoted intervals.

Level 3 inputs are unobservable inputs for the asset or liability, and are typically based on an entity’s own assumptions, as there is little, if any, related market activity.

In instances where the determination of the fair value measurement is based on inputs from different levels of the fair value hierarchy, the level in the fair value hierarchy within which the entire fair value measurement falls is based on the lowest level input that is significant to the fair value measurement in its entirety. Our assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment, and considers factors specific to the asset or liability. We utilize the fair value hierarchy in our accounting for interest rate swaps (Level 2).

Related party consulting agreement

The Company and Goodrich entered into a Consulting Agreement dated effective June 1, 2014 (the “2014 Consulting Agreement”). The 2014 Consulting Agreement will pay Goodrich $360,000 per annum in installments of $30,000 per month, in addition to reimbursing Goodrich for all reasonable business expenses, including automobile expenses, incurred by Mr. Tsuff in connection with services rendered on behalf of the Company, in exchange for management services performed by Mr. Tsuff as the Company’s Chairman, Co-Chief Executive Officer and President. These payments of $360,000 constitute the salary of Mr. Tsuff. The 2014 Consulting Agreement had an initial term through May 31, 2017, and was automatically extended by its terms for an additional three-years. The Consulting Agreement also contains certain customary confidentiality and non-compete provisions which are identical to those contained in the Goodrich Agreement.

Consolidation

The consolidated financial statements include the accounts of Isramco and its subsidiaries. Inter-company balances and transactions have been eliminated in consolidation.

Cash, cash equivalents and restricted cash

The Company considers highly liquid investments purchased with a maturity period of three months or less at the date of purchase to be cash equivalents. Restricted and designated cash and restricted cash – long term are included with cash, cash equivalents, and restricted cash on the Company’s consolidated statements of cash flows.

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Consolidated balance sheets amount included as cash, cash equivalents, and restricted cash on the Company’s consolidated statements of cash flows:

	As of June 30, 2019		As of December 31, 2018

Cash and cash equivalents	$	12,742	$	13,857
Restricted and designated cash		832		830
Restricted cash – long term		21,543		19,304
Total cash, cash equivalents, and restricted cash	$	35,117	$	33,991

Leases

In February 2016, the FASB issued ASU 2016-02, "Leases" (Topic 842) The new standard requires lessees to recognize leases on-balance sheet and disclose key information about leasing arrangements. The new standard establishes a right-of-use (“ROU”) model that requires a lessee to recognize a ROU asset and lease liability on the balance sheet for all leases with a term longer than 12 months. Leases will be classified as finance or operating, with classification affecting the pattern and classification of expense recognition in the income statement. The standard is effective on January 1, 2019, with early adoption permitted. The Company adopted the new standard on January 1, 2019 using the modified retrospective method. As part of the adoption, the Company elected to utilize the package of practical expedients included in this guidance, which permitted the Company to not reassess (i) whether any expired or existing contracts contain leases; (ii) the lease classification for any expired or existing leases; and (iii) the initial direct costs for existing leases. In conjunction with the adoption of the new lease standard, the Company adopted the following policy; an election not to recognize short-term leases (i.e., a lease that is less than 12 months and contains no purchase option) within the unaudited Consolidated Balance Sheets, with the expense related to these short-term leases recorded within total operating expenses within the unaudited Consolidated Statements of Operations. The adoption of the new standard did not materially impact the financial statements.

Impairment

We review our property and equipment in accordance with Accounting Standards Codification (ASC) 360, Property, Plant, and Equipment (ASC 360). ASC 360 requires us to evaluate property and equipment as an event occurs or circumstances change that would more likely than not reduce the fair value of the property and equipment below the carrying amount. If the carrying amount of property and equipment is not recoverable from its undiscounted cash flows, then we would recognize an impairment loss for the difference between the carrying amount and the current fair value. Further, we evaluate the remaining useful lives of property and equipment at each reporting period to determine whether events and circumstances warrant a revision to the remaining depreciation periods.

Asset Retirement Obligation

ASC 410, Asset Retirement and Environmental Obligations (ASC 410) requires that the fair value of an asset retirement cost, and corresponding liability, should be recorded as part of the cost of the related long-lived asset and subsequently allocated to expense using a systematic and rational method. The Company records asset retirement obligations to reflect the Company’s legal obligations related to future plugging and abandonment of its oil and natural gas wells and gas gathering systems. The Company estimates the expected cash flow associated with the obligation and discounts the amounts using a credit-adjusted, risk-free interest rate. At least annually, the Company reassesses the obligation to determine whether a change in the estimated obligation is necessary. The Company evaluates whether there are indicators that suggest the estimated cash flows underlying the obligation have materially changed. Should those indicators suggest the estimated obligation may have materially changed on an interim basis (quarterly), the Company will accordingly update its assessment.

Gain on divestiture

In February 2018, the Company sold an oil and gas property for a net gain of $472,000. The gain consisted of $454,000 cash plus $19,000 in relieved asset retirement obligation offset by a net book value of $1,000. The Company had no such sales in the first six months of 2019.

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Commitments and Contingencies

As is common within the oil and natural gas industry, we have entered into various commitments and operating agreements related to the exploration and development of and production from proved oil and natural gas properties. It is our belief that such commitments will be met without a material adverse effect on our financial position, results of operations or cash flows.

Aggregate maturities of contractual obligations at June 30, 2019, are due in future years as follows (in thousands):

Principal Payments on Long-term debt:

2019	$	10,800
2020		17,100
2021		14,700
2022		14,400
2023		11,400
Total	$	68,400

Proposed Merger Transaction

As previously disclosed in the Company’s Current Report on Form 8-K filed with the SEC on May 20, 2019, on May 20, 2019, Isramco entered into an Agreement and Plan of Merger (the “Merger Agreement”), by and among Isramco, Naphtha Israel Petroleum Corporation Ltd., an Israeli public company (“Naphtha”), Naphtha Holding Ltd., an Israeli private company and a direct wholly owned subsidiary of Naphtha (“NHL”), I.O.C. - Israel Oil Company, Ltd., an Israeli private company and a direct wholly owned subsidiary of Naphtha (“Parent”), and Naphtha US Oil, Inc., a Delaware corporation and a direct wholly owned subsidiary of Parent (“Merger Sub” and, together with Naphtha, NHL and Parent, the “Purchaser Parties,” and together with Isramco, each a “Party” and collectively the “Parties”) providing for the merger of Merger Sub with and into Isramco (the “Merger”), with Isramco surviving the Merger as a subsidiary of Parent and NHL. Mr. Haim Tsuff is the chief executive officer and the chairman of the board of directors (the “Board”) of Isramco. Mr. Tsuff is the sole director and owner of United Kingsway Ltd. which holds 74.0% of the outstanding membership interests in each of YHK Investment L.P. (“YHP LP”), an Israeli limited partnership, and YHK General Manager Ltd. (“YHK Manager”), an Israeli private company that serves as the general partner of YHP LP. Mr. Tsuff is the chairman of YHK Manager (which entity effectively controls Naphtha, NHL and Parent) and currently beneficially owns approximately 73.0% of the outstanding shares of Isramco’s common stock, par value $0.01 per share (the “Common Stock”).

At the effective time of the Merger, each issued and outstanding share of Common Stock, other than shares owned by Isramco as treasury stock, shares owned by NHL or Parent, and shares owned by holders of Common Stock who shall neither have voted in favor of the Merger nor consented thereto in writing and who shall have properly and validly perfected, and not effectively withdrawn or lost, their statutory appraisal rights under Delaware law (such shares of Common Stock “dissenting shares”), will be converted into the right to receive $121.40 in cash per share, without interest and subject to any withholding taxes (the “Merger Consideration”).

The Board (other than Mr. Tsuff, who recused himself from the vote of the Board), acting upon the recommendation of a special committee of independent and disinterested directors (the “Special Committee”), (i) determined that the Merger Agreement and the transactions contemplated thereby (the “Contemplated Transactions”), including the Merger, are advisable and fair to, and in the best interests of, Isramco and Isramco’s stockholders, other than the Purchaser Parties or any of their affiliates (together, the “Purchaser Group”) and any officer of Isramco as determined in accordance with Rule 16a-1(f) promulgated under Securities Exchange Act of 1934, as amended (together, the “Section 16 Officers”), (ii) approved the Merger Agreement and the Contemplated Transactions, including the Merger, and (iii) resolved to recommend that Isramco’s stockholders approve the adoption of the Merger Agreement.

In connection with the Merger Agreement, Parent, Isramco, NHL and Mr. Tsuff entered into a Voting and Support Agreement, dated as of May 20, 2019 (the “Support Agreement”). Per the terms and conditions set forth in the Support Agreement, Parent, NHL and Mr. Tsuff have each agreed to vote, or cause to be voted, all shares of Common Stock beneficially owned by each such party (representing an aggregate of approximately 73.0% of Isramco’s total outstanding voting power as of March 31, 2019) for the adoption of the Merger Agreement. For additional information regarding the Support Agreement, please see the Company’s disclosure set forth on the Company’s Current Report on Form 8-K filed with the SEC on May 20, 2019, Preliminary Proxy Statement filed with the SEC on August 1, 2019 (the “Preliminary Proxy Statement”), and Schedule 13E-3 filed with the SEC on August 1, 2019.

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In connection with the Merger Agreement, Isramco has also entered into indemnification agreements (the “Indemnification Agreements”) with the members of the Board that reiterate the indemnification rights provided in Isramco’s governing documents and the Merger Agreement. For additional information regarding the Indemnification Agreements, please see the Company’s disclosure set forth on the Company’s Current Report on Form 8-K filed with the SEC on May 20, 2019 and the Preliminary Proxy Statement filed with the SEC on August 1, 2019.

In connection with the proposed Merger, the Company filed a Preliminary Proxy Statement with the SEC on August 1, 2019. Once any SEC comments to the Preliminary Proxy Statement are received, responded to, and resolved, the Company will set a record and meeting date for the annual meeting of the Company’s stockholders to approve the Merger and the Contemplated Transactions. If the Company’s shareholders approve the Merger as required by the Merger Agreement and described in the Preliminary Proxy Statement, and other closing conditions are met, the Merger and the Contemplated Transactions will close shortly thereafter.

For additional information regarding the Merger Agreement, the Support Agreement, and the Indemnification Agreements, please see the Company’s disclosure set forth on the Company’s Current Report on Form 8-K filed with the SEC on May 20, 2019, Preliminary Proxy Statement filed with the SEC on August 1, 2019, and Schedule 13E-3 filed with the SEC on August 1, 2019.

The foregoing descriptions of the Merger Agreement, the Support Agreement, and the Indemnification Agreements do not purport to describe all of the terms of such agreements and are qualified in their entirety by the full text of such agreements, copies of which are filed as Exhibits 2.1, 10.1, and 10.2, respectively, to this Quarterly Report on Form 10-Q.

Note 2 - Supplemental Cash Flow Information

The Israeli taxing authority withheld taxes of $3,568,000 and $3,444,000 during the six months ended June 30, 2019 and 2018 respectively.

Cash payments for interest were $2,069,000 and $2,106,000 for the six-month periods ended June 30, 2019 and 2018 respectively.

The consolidated statement of cash flows for the six-month period ended June 30, 2019 excludes the following non-cash transactions:

●	Increase in property and equipment of $128,000 included in accounts payable.

The consolidated statement of cash flows for the six-month period ended June 30, 2018 excludes the following non-cash transactions:

●	Increase in property and equipment of $165,000 included in accounts payable.

●	Asset retirement obligation relieved of $19,000 due to sale of oil and gas properties.

Note 3 – Revenue from Contracts with Customers

Below is a discussion of the nature, timing, and presentation of revenues arising from the Company’s major revenue-generating arrangements:

Oil and Gas Sales United Sates – Revenues on sales of oil, natural gas liquids (“NGLs”), gas and purchased oil and gas are recognized when control of the product is transferred to the purchaser and payment can be reasonably assured. Sales prices for oil, NGL and gas production are negotiated based on factors normally considered in the industry, such as an index or spot price, distance from the well to the pipeline or market, commodity quality and prevailing supply and demand conditions. As such, the prices of oil, NGLs and gas generally fluctuate based on the relevant market index rates. Sales under the Company’s oil contracts are generally considered performed when the Company sells oil production at the wellhead and receives an agreed-upon index price, net of any price differentials. The Company recognizes revenue when control transfers to the purchaser at the wellhead based on the net price received. Sales under the Company’s gas processing contracts are recognized when the Company delivers gas to a midstream processing entity at the wellhead or the inlet of the midstream processing entity’s system. The midstream processing entity gathers and processes the gas and remits proceeds to the Company for the resulting sales of NGLs and gas.

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In a few cases, the Company elects to take its NGLs and residue gas in-kind at the tailgate of the midstream entity’s processing plant and subsequently market the products itself. When the Company elects to take-in-kind, it delivers NGLs and gas to a third-party purchaser at a contractually agreed-upon delivery point and receives a specified index price from the purchaser.

Natural Gas Sales Israel – We own all ownership units in Tamar Royalties LLC, a Delaware limited liability company. Tamar Royalties LLC owns an overriding royalty interest of 1.5375% before payout, which increases to 2.7375% after payout, in the Tamar Field (collectively the “Tamar Royalty”) offshore Israel. An overriding royalty interest is an ownership interest in the oil and gas leasehold estate equating to a certain percentage of production or production revenues, calculated free of the costs of production and development of the underlying lease(s), but subject to its proportionate share of certain post production costs. An overriding royalty interest is a non-possessory interest in the oil and gas leasehold estate and, accordingly, we have no control over the operations, drilling, expenses, timing, production, sales, or any other aspect of development or production of the Tamar Field.

Natural gas from the Tamar Field is currently sold to the Israel Electric Corporation (“IEC”) and numerous other Israeli purchasers, including independent power producers, cogeneration facilities, local distribution companies and certain industrial companies. Currently, many of the Tamar’s gas purchase and sale agreements provide for sales at a 7 to 15-year term, while some contracts have extension options of up to 2 years. Depending on the specific contract, prices may vary and are based on an initial base price subject to price adjustment provisions, including price indexation and a price floor. The IEC contract provides for price reopeners (sometimes referred to as “price review” clauses) in the eighth and eleventh years of the contract, subject to limits on the amount of increase or decrease from the existing contractual price.

Revenues from natural gas sales in Israel are recognized when control of the product is transferred to a purchaser and payment can reasonably be assured. The Company receives monthly overriding royalty payments from Isramco Negev 2 Limited Partnership, a related party. We generally receive payment two months after the hydrocarbons have been produced. The revenue is recognized in the month that the hydrocarbons are produced.

Production Services – Our production services business earns revenues for well servicing, plugging and abandonment services, workover, and fluid hauling services pursuant to master service agreements based on purchase orders or other contractual arrangements with the customer. Production services jobs are generally short-term (less than 30 days) and are charged at current market rates for the labor, equipment and materials necessary to complete the job. Production services jobs are varied in nature, but typically represent a single performance obligation, either for a particular job, a series of distinct jobs, or a period of time during which we stand ready to provide services as our customer needs them. Generally, the Company accounts for production services as a single performance obligation satisfied at a certain point in time. Revenue for certain jobs spanning multiple days is recognized upon the completion of each day’s work based upon a completed field ticket, which includes the charges for the services performed, mobilization of the equipment to the location and personnel. Additional revenue is generated through labor charges and the sale of consumable supplies that are incidental to the service being performed. Such amounts are recognized ratably over the period during which the corresponding goods and services are consumed.

Disaggregation of revenues (in thousands):

	Six Months Ended June 30,
	2019		2018
Oil and Gas sales
United States	$	6,344	$	7,793
Israel		15,512		14,974
Production Services		17,248		13,690
Total revenues from contracts with customers	$	39,104	$	36,457

Performance obligations

The Company satisfies the performance obligations under its crude oil and natural gas sales contracts upon delivery of its production and related transfer of title to customers. Upon delivery of production, the Company has a right to receive consideration from its customers in amounts that correspond with the value of the production transferred. The Company satisfies the performance obligations under production services arrangements by completing the contracted job, at which time the Company as the right to receive consideration from its customers in agreed upon amounts.

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All of the Company’s outstanding production services and crude oil sales contracts at June 30, 2019 are short-term in nature with contract terms of less than one year. For such contracts, the Company has utilized the practical expedient in Accounting Standards Codification (“ASC”) 606-10-50-14 exempting the Company from disclosure of the transaction price allocated to remaining performance obligations, if any, if the performance obligation is part of a contract that has an original expected duration of one year or less.

Most of the Company’s operated natural gas production is sold at lease locations to midstream customers under multi-year term contracts. For such contracts having a term greater than one year, the Company has utilized the practical expedient in ASC 606-10-50-14A which indicates an entity is not required to disclose the transaction price allocated to remaining performance obligations, if any, if variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under our sales contracts, whether for crude oil or natural gas, each unit of production delivered to a customer represents a separate performance obligation; therefore, future volumes to be delivered are wholly unsatisfied at period-end and disclosure of the transaction price allocated to remaining performance obligations is not applicable.

Contract balances

Under the Company’s crude oil and natural gas sales contracts or arrangements that give rise to service revenues, the Company recognizes revenue after its performance obligations have been satisfied, at which point the Company has an unconditional right to receive payment. Accordingly, the Company’s commodity sales contracts and service arrangements generally do not give rise to contract assets or contract liabilities under ASC Topic 606. Instead, the Company’s unconditional rights to receive consideration are presented as a receivable within “Accounts receivable, net of allowances for doubtful accounts,” in its consolidated balance sheets.

Revenues from previously satisfied performance obligations

To record revenues for commodity sales in the United States and Israel, at the end of each period the Company estimates the amount of production delivered and sold to customers and the prices to be received for such sales. Differences between estimated revenues and actual amounts received for all prior months are recorded in the month payment is received from the customer and are reflected in our consolidated financial statements within the caption “Oil and gas sales.” Revenues recognized during the six months ended June 30, 2019 related to performance obligations satisfied in prior reporting periods were not material.

To record revenues for unbilled production services, at the end of each period the Company estimates the services rendered. Differences between estimated revenues and actual amounts received for all prior months are recorded in the month invoices are created and reflected in our consolidated financial statement with the caption “Production services.” The Company believes that revenues recognized during the six months ended June 30, 2019 related to performance obligations satisfied in prior reporting periods were not material.

Note 4 - Financial Instruments and Fair Value

Pursuant to ASC 820, Fair Value Measurements and Disclosures (ASC 820) the Company’s determination of fair value incorporates not only the credit standing of the counterparties involved in transactions with the Company resulting in receivables on the Company’s consolidated balance sheets, but also the impact of the Company’s non-performance risk on its own liabilities. ASC 820 defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). The Company believes that it utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable. The Company classifies fair value balances based on the observability of those inputs.

On June 16, 2015, Tamar Royalties LLC (“Tamar Royalties”), a wholly owned subsidiary of the Company, engaged in an interest rate swap agreement (“IRS Agreement”) with the Deutsche Bank AG London Branch (“DBAG”). An interest rate swap is an agreement between two parties (known as counterparties) where one stream of future interest payments is exchanged for another based on a specified notional principal amount. Interest rate swaps often exchange fixed interest payments for floating interest payments that are linked to interest rates.

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As previously disclosed on the Company’s Form 8-K filed May 22, 2015, Tamar Royalties entered into a $120,000,000 credit facility with Deutsche Bank, which facility is discussed further in Note 5 “Long-Term Debt and Interest Expense”. Under the terms of this facility, Tamar Royalties, is required to hedge at least seventy-five percent (75%) of the outstanding balance under this facility against fluctuations in LIBOR, with at least thirty-seven and one-half percent (37.5%) of the outstanding balance being hedged through swaps. The notional value of these hedges corresponds to the amortization schedule covering the facility and previously disclosed in the aforementioned Form 8-K. Accordingly, on June 16, 2015, Tamar Royalties and DBAG entered into the IRS Agreement whereby the Company hedged $119,250,000 of the $120,000,000 initial borrowing as follows:

(a) Tamar Royalties hedged 37.5% of the perpetual outstanding balance under the facility, being an initial notional amount of $45,000,000, with a fixed rate swap whereby the Company will pay DBAG a fixed interest rate of 4.63%, and DBAG will pay the Company a monthly floating interest rate of USD-LIBOR-BBA plus a spread of 2.75%.

(b) Tamar Royalties hedged the remaining 62.5% of the perpetual outstanding balance less $750,000, being an initial notional amount of $74,250,000, against fluctuations in LIBOR by capping the fluctuations in LIBOR at 1.50%. Pursuant to the IRS Agreement, the Company will pay DBAG a fixed interest rate of 0.91%, and DBAG will pay the Company the greater of (i) USD-LIBOR-BBA minus a cap strike of 1.5% and (ii) zero.

As a result of these financial instruments, the Company recorded a net loss from derivative contracts in the amount of $846,000, consisting of $991,000 of unrealized loss and $145,000 gain in cash settlements for the six months ended June 30, 2019. The Company recorded a net gain from derivative contracts in the amount of $1,148,000 consisting of $1,467,000 of unrealized gain and $319,000 loss in cash settlements for the six months ended June 30, 2018.

Financial Instruments as of June 30, 2019 and December 31, 2018 consisted of the following (in thousands):

		June 30, 2019						December 31, 2018
Financial Instrument	Fair Value Input Level	Carrying			Fair			Carrying		Fair
		Value			Value			Value		Value

ST Assets:
Interest rate swaps	Level 2	$	16		$	16		$	293	$	293

LT Assets/Liabilities:
Interest rate swaps	Level 2		(326	)		(326	)		388		388

		$	(310	)	$	(310	)	$	681	$	681

Level 2 Financial Instruments

Our interest rate swaps are measured at fair value using Level 2 inputs. The fair of our interest rate swaps is based on the net present value of expected future cash flows related to both variable and fixed-rate legs of the swap agreement. This measurement is computed using the forward London Interbank Offered Rate (“LIBOR”) yield curve, a market-based observable input.

Note 5 - Long-Term Debt and Interest Expense

Long-term debt as of June 30, 2019 and December 31, 2018 consisted of the following (in thousands):

	As of June 30, 2019			As of December 31, 2018
Bank loan
Principal amount	$	68,400		$	79,500
Less: unamortized discount and debt costs		(1,749	)		(2,131	)
Total long-term debt		66,651			77,369
Less: current maturities, net of current unamortized discount		(19,468	)		(21,176	)

Long-term debt, net of current maturities	$	47,183		$	56,193

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Bank Loan

The Deutsche Bank Facility

On May 18, 2015, Tamar Royalties, a newly formed, wholly-owned, special purpose subsidiary of the Company, entered into a term loan credit agreement (the “DB Facility”) with Deutsche Bank Trust Company Americas (“Deutsche Bank”), as facility agent for the lenders and as collateral agent for the secured parties, and with the lenders party thereto. The DB Facility provides for borrowings in the amount of $120,000,000 on a committed basis and is secured by, among other things, an overriding royalty interest in the Tamar Field, a natural gas field in the Mediterranean Sea, equal to 1.5375%, but is subject to increase to 2.7375% upon the Tamar project payout (the “Royalty Interest”). In connection with the DB Facility, and pursuant to a royalties sale and contribution agreement, the Company contributed the Royalty Interest to Tamar Royalties in exchange for all of the ownership units of Tamar Royalties. Pursuant to the terms of its governing documents, Tamar Royalties is managed by N.M.A. Energy Resources Ltd, a related party of the Company, and an independent manager, Donald J. Puglisi.

Pursuant to the terms of the DB Facility, Tamar Royalties borrowed $120,000,000 in its initial borrowing under this facility. The initial borrowing under the DB Facility bears annual interest based on the LIBOR for a three-month interest period plus a spread of 2.75%. The $120,000,000 initial borrowing under the DB Facility will be repaid over eight (8) years commencing July 1, 2015, in accordance with an amortization profile based on projected cash flows from the Royalty Interest. Tamar Royalties’ obligations under the DB Facility are secured by a first ranking pledge of the shares of Tamar Royalties, first ranking pledge of all rights under the agreements creating the Royalty Interest, and a first priority security interest over the accounts created under the DB Facility.

So long as any amounts remain outstanding to the Lenders under the DB Facility, Tamar Royalties must, from and after the end of the Availability Period (as defined in the DB Facility), have a Historical Debt Service Coverage Ratio (as defined in the DB Facility) of not less than 1.00:1.00, a Loan Life Coverage Ratio (as defined in the DB Facility) of at least 1.1:1.00, and maintain a Required Reserve Amount (as defined in the DB Facility). The initial Required Reserve Amount was $4,680,000. In addition, Tamar Royalties is required under the DB Facility to hedge against fluctuations in LIBOR as reflected in Note 4 “Financial Instruments and Fair Value”.

The amortization schedule under the DB Facility was based on the projection that the Investment Repayment Date (as defined therein) would occur at some point before the end of the first quarter of 2018 and therefore, commencing from the Payment Date occurring on 1st April 2018, the amounts to be repaid on each payment date under the credit agreement increase to reflect the expected increase in the Royalties Receivables (as defined therein) as a result of the increase in the royalty percentage following the Investment Repayment Date.

With regard to the payout of the Tamar Field, disagreements between the Company and Isramco Negev 2 Limited Partnership have emerged as to what costs should be included in the calculation of payout. The disagreements primarily stem from the fact that the agreements governing the creation of the Tamar Royalty were formulated in the 1980s and do not have a clear and unequivocal definition as to what costs should be included in the payout calculation. In addition to actual costs for the development of the Tamar Field, Isramco, Negev 2 Limited Partnership has asserted that the following costs should be included in the calculation of payout: (i) Isramco Negev 2 Limited Partnership’s financing costs; (ii) the general and administrative expenses of Isramco Negev 2 Limited Partnership; (iii) the expected decommissioning costs of the Tamar Field; and (iv) expected future payments to be made in respect of the “Sheshinsky Levy” under Israeli law. In addition to the claim asserted by Isramco Negev 2 Limited Partnership, the Company has asserted counterclaims related to Isramco Negev 2 Limited Partnership’s inclusion into the payout calculation of charges related to gathering and transportation infrastructure. At the time of initiating arbitration, the Company believed that the total scope of the claim asserted by Isramco Negev 2 Limited Partnership was approximately forty-five million dollars ($45,000,000); however, this amount increases each month based on Isramco Negev 2 Limited Partnership’s failure to pay the increased, post-payout overriding royalty to the Company. In addition, certain claims and the counterclaims asserted by the Company related to post production costs and pipeline infrastructure have not been quantified. Under the terms of the agreements creating the Tamar Royalty, the dispute is subject to arbitration in Israel. The Company believes that the claims of Isramco Negev 2 Limited Partnership are erroneous and contrary to generally accepted industry practice. The Company expects that the matter will be favorably resolved through this arbitration process; however, the Company cannot be assured of a favorable result in this arbitration process. Accordingly, the Company continues to receive royalty payments at the lower rates as if the Investment Repayment Date has not occurred.

Therefore, as a result of the dispute with the Isramco Negev 2, Tamar Royalties had a shortfall in its Royalties Receivables for the period (or part of the period) between 1st April 2018 and 1st April 2019.

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As a result, the Company believed Tamar Royalties required an additional $15,600,000 USD to cover payments under the amortization schedule of the DB Facility (the “Shortfall”), and the Company believed that curing the Shortfall was in the best interest of both Isramco Inc. and Tamar Royalties. Therefore, Isramco Inc. contributed the expected amount of the Shortfall, being $15,600,000 USD, to Tamar Royalties as an additional capital contribution and such contribution was made pursuant to the terms and conditions of that certain Consent and Agreement dated February 27, 2018, between and among Tamar Royalties, as Borrower, Deutsche Bank Trust Company Americas, as Facility Agent and Collateral Agent, and the Lenders party thereto. As a result of the aforementioned contribution, together with the terms and conditions of the aforementioned consent and assignment, Tamar Royalties remains in compliance with all covenants of the DB Facility.

On January 2, 2019, the Company made a payment in the amount of $6,757,000 consisting of $5,700,000 and $1,057,000 in principal and interest respectively.

On April 2, 2019, the Company made a payment in the amount of $6,412,000 consisting of $5,400,000 and $1,012,000 in principal and interest respectively.

On July 1, 2019, the Company made a payment in the amount of $6,324,000 consisting of $5,400,000 and $924,000 in principal and interest respectively.

The Company incurred debt costs in obtaining the facility in the amount of $2,011,000. Additionally, the lenders retained $2,959,000 in fees. These costs, totaling $4,970,000, are recorded as a reduction of the principal loan balance and are being amortized over the life of the loan using the effective interest method. Amortization of these costs for the six-month period ended June 30, 2019 and 2018 totaled $382,000 and $411,000 respectively.

Short-term related party debt

In September 2018, the Company issued an unsecured promissory note dated effective September 11, 2018, to I.O.C - Israel Oil Company LTD (“IOC”) a related party in which the company may borrow up to $7,000,000 at a rate of interest equal to seven and one-half percent (7.5%) and with a maturity date of September 2019. The company received $3,600,000 under this related party note in 2018 attendant with the creation of a new subsidiary, Arrow Midstream LLC. In January 2019 the Company received an additional $600,000 under this related party note. The principal balance outstanding as of June 30, 2019 and December 31, 2018 was $4,200,000 and $3,600,000 respectively. The accrued interest related to this promissory note as of June 30, 2019 and December 31, 2018 was $224,000 and $70,000 respectively.

Amounts received under the aforementioned promissory note are dedicated to working capital and the purchase of equipment for Arrow Midstream LLC, a new wholly owned subsidiary of Isramco Inc. Arrow Midstream is focused on the transportation of liquefied petroleum products including, but not limited to, butane, propane, and similar products.

Mr. Haim Tsuff, Isramco’s Co-Chief Executive Officer and Chairman may be deemed to control IOC.

As of June 30, 2019, Tamar Royalties was in compliance with the financial covenants required under the DB Facility.

Short-Term Debt

As of June 30, 2019, and December 31, 2018, outstanding debt from short-term insurance financing agreements totaled $80,000 and $563,000 respectively. During the six months ended June 30, 2019, the Company made cash payments totaling $483,000.

Interest Expense

The following table summarizes the amounts included in interest expense for the six months ended June 30, 2019, and 2018:

	Six Months Ended June 30,
	2019		2018
	(In thousands)
Current debt, long-term debt and other - banks	$	1,963	$	2,550
Long-term debt – related parties		154		-
	$	2,117	$	2,550

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Note 6 - Tamar Field Proceeds

We own an overriding royalty interest of 1.5375% in the Tamar Field, which will increase to 2.7375% after payout (collectively the “Tamar Royalty”). An overriding royalty interest is an ownership interest in the oil and gas leasehold estate equating to a certain percentage of production or production revenues, calculated free of the costs of production and development of the underlying lease(s), but subject to its proportionate share of certain post production costs. An overriding royalty interest is a non-possessory interest in the oil and gas leasehold estate and, accordingly, we have no control over the operations, drilling, expenses, timing, production, sales, or any other aspect of development or production of the Tamar Field. For additional information, please see the disclosure related to the Tamar Royalty set forth in the ITEM 1. BUSINESS section included in our Annual Report on Form 10-K for the year ended December 31, 2018, which disclosure is hereby incorporated herein by reference thereto.

In 2009, two natural gas discoveries, known as “Tamar” and “Dalit”, were made within the area covered by the Michal and Matan Licenses, respectively. In December 2009, the Israeli Petroleum Commissioner granted Noble Energy, Inc. (“Noble”) and its partners, Isramco Negev 2-LP, Delek Drilling, Avner Oil & Gas, and Dor Gas (the “Tamar Consortium”), two leases (the “Leases”). The Leases are scheduled to expire in December 2038 and cover the Tamar and Dalit gas fields (collectively the “Tamar Field”). The Tamar Field is approximately 95 kilometers off the coast of the Israel, in the Israel exclusive economic zone of the Eastern Mediterranean, with a water depth of approximately 1,700 meters. On March 31, 2013 the Tamar Field commenced its initial production of the natural gas.

Since Isramco’s interest in the Tamar Field is an overriding royalty interest, there are no amounts capitalized with respect to Tamar Field.

During the six months ended June 30, 2019, Tamar Field net sales attributable to Isramco amounted to 2,786,663 Mcf of natural gas and 3,566 Bbl of condensate with prices of $5.51 per Mcf and $58.59 per Bbl of condensate. Total revenues net of marketing and transportation expenses were $15,512,000. The Israeli Tax Authority withheld $3,568,000 of this revenue.

During the six months ended June 30, 2018, Tamar Field net sales attributable to Isramco amounted to 2,730,748 Mcf of natural gas and 3,492 Bbl of condensate with prices of $5.43 per Mcf and $63.25 per Bbl of condensate. Total revenues net of marketing and transportations expenses were $14,974,000. The Israeli Tax Authority withheld $3,444,000 of this revenue which is recognized as a future tax credit.

Note 7 - Segment Information

Isramco’s primary business segments are vertically integrated within the oil and gas industry. These segments are separately managed due to distinct operational differences, unique technology, distribution and marketing requirements. The Company’s two reporting segments are oil and gas exploration and production and production services. The oil and gas exploration and production segment explores for and produces natural gas, crude oil, condensate, and natural gas liquids (“NGLs”). The production services segment is engaged in rig-based and workover services, well completion and recompletion services, plugging and abandonment of wells and other ancillary oilfield services.

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Oil and Gas Exploration and Production Segment

Our Oil and Gas segment is engaged in the exploration, development and production of oil and natural gas properties located onshore in the United States and ownership of various royalty interests in oil and gas concessions located offshore Israel. We own varying working interests in oil and gas wells in Louisiana, Texas, New Mexico, Oklahoma, Wyoming, Utah and Colorado and currently serve as operator of approximately 422 producing wells located mainly in Texas in New Mexico.

Production Services Segment

The Company began production services operations in October 2011. Our production servicing rig and truck fleet provides a range of production services, including the completion of newly-drilled wells, maintenance and workover of existing wells, fluid transportation, related oilfield services and plugging and abandonment of wells at the end of their useful lives to a diverse group of oil and gas exploration and production companies.

●

Completion Service. Newly drilled wells require completion services to prepare the well for production. Production servicing rigs are frequently used to complete newly drilled wells to minimize the use of higher cost drilling rigs in the completion process. The completion process may involve selectively perforating the well casing in the productive zones to allow oil or gas to flow into the well bore, stimulating and testing these zones, and installing the production string and other downhole equipment. The completion process typically ranges from a few days to several weeks, depending on the nature and type of the completion, and generally requires additional auxiliary equipment in addition to a production services rigs. The demand for completion services is directly related to drilling activity levels, which are sensitive to fluctuations in oil and gas prices.

●

Well-servicing/Maintenance Services. We provide maintenance services on the mechanical apparatus used to pump or lift oil from producing wells. These services include, among other activities, repairing and replacing pumps, sucker rods and tubing. We provide the rigs, equipment and crews for these tasks, which are performed on both oil and natural gas wells, but which are more commonly required on oil wells. Maintenance services typically take less than 48 hours to complete. Rigs generally are provided to customers on a call-out basis.

●

Workover Services. Producing oil and natural gas wells occasionally require major repairs or modifications, called “workovers.” Workovers may be required to remedy failures, modify well depth and formation penetration to capture hydrocarbons from alternative formations, clean out and recomplete a well when production has declined, repair leaks or convert a depleted well to an injection well for secondary or enhanced recovery projects. Workovers normally are carried out with pumps and tanks for drilling fluids, blowout preventers, and other specialized equipment for servicing rigs. A workover may last anywhere from a few days to several weeks.

●

Fluid Services. We own and operate 35 fluid service trucks equipped with an average fluid hauling capacity of up to 130 barrels a piece. Each fluid service truck is equipped to pump fluids from or into wells, pits, tanks and other storage facilities. The majority of our fluid service trucks are also used to transport water to fill frac tanks on well locations, to transport produced salt water to disposal wells, and to transport drilling and completion fluids to and from well locations.

●

Plugging Services. Production servicing rigs are also used in the process of permanently closing oil and gas wells that are no longer capable of producing in economically viable quantities. Many well operators bid for this work on a “turnkey” basis, requiring the service company to perform the entire job, including the sale or disposal of equipment salvaged from the well as part of the compensation received, and complying with state regulatory requirements. Plugging and abandonment work can provide favorable operating margins and is less sensitive to oil and gas pricing than drilling and workover activity since well operators must plug a well in accordance with state regulations when it is no longer productive. We perform plugging and abandonment work throughout our core areas of operation in conjunction with equipment provided by us or by other service companies.

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We typically bill clients for our production servicing on an hourly basis for the period that the rig is actively working. As of June 30, 2019, our fleet of production servicing rigs totaled 33 rigs, which we operate through 5 locations in Texas and New Mexico.

(in thousands)	Oil and Gas Exploration & Production			Production Services			Eliminations			Total
Three Months Ended June 30, 2019:
Sales revenues
United States	$	3,127		$	7,816		$	-		$	10,943
Israel		7,411			-			-			7,411
Intersegment revenues		-			-			-			-
Office services and other		298			-			(30	)		268

Total revenues and other		10,836			7,816			(30	)		18,622

Operating costs and expenses		4,419			7,996			(30	)		12,385
Depreciation, depletion, and amortization		350			1,023			-			1,373
Interest expenses, net		(542	)		1,475			-			933
Gain on derivative contracts		513			-			-			513
Other income, net		1			2			-			3

Total expenses and other		4,741			10,496			(30	)		15,207

Income (loss) before income taxes	$	6,095		$	(2,680	)	$	-		$	3,415
Net Income (loss)		3,567			(1,857	)		-			1,710
Net loss attributable to noncontrolling interests		-			(557	)		-			(557	)
Net income (loss) attributable to Isramco		3,567			(1,300	)		-			2,267
Total Assets	$	60,984		$	45,758		$	-		$	106,742
Expenditures for Long-lived Assets	$	157		$	498		$	-		$	655

(in thousands)	Oil and Gas Exploration & Production			Production Services			Eliminations			Total
Three Months Ended June 30, 2018:
Sales revenues
United States	$	4,018		$	7,927		$	-		$	11,945
Israel		7,765			-			-			7,765
Intersegment revenues		-			88			(88	)		-
Office services and other		312			-			(30	)		282

Total revenues and other		12,095			8,015			(118	)		19,992

Operating costs and expenses		3,860			7,565			(118	)		11,307
Depreciation, depletion, and amortization		537			918			-			1,455
Interest expenses, net		114			1,219			-			1,333
Gain on derivative contracts		(283	)		-			-			(283	)
Other income, net		11			-			-			11

Total expenses and other		4,239			9,702			(118	)		13,823

Income (loss) before income taxes	$	7,856		$	(1,687	)	$	-		$	6,169
Net Income (loss)		5,693			(1,310	)		-			4,383
Net loss attributable to noncontrolling interests		-			(325	)		-			(325	)
Net income (loss) attributable to Isramco		5,693			(985	)		-			4,708
Total Assets	$	61,997		$	48,238		$	-		$	110,235
Expenditures for Long-lived Assets	$	108		$	1,819		$	-		$	1,927

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(in thousands)	Oil and Gas Exploration & Production			Production Services			Eliminations			Total
Six Months Ended June 30, 2019:
Sales revenues
United States	$	6,344		$	17,248		$	-		$	23,592
Israel		15,512			-			-			15,512
Intersegment revenues		-			173			(173	)		-
Gain on divestiture, office services and other		594			-			(60	)		534

Total revenues and other		22,450			17,421			(233	)		39,638

Operating costs and expenses		8,474			16,818			(233	)		25,059
Depreciation, depletion, and amortization		735			1,968			-			2,703
Interest expenses, net		(803	)		2,920			-			2,117
Gain on derivative contracts		846			-			-			846
Other income, net		(1	)		2			-			1

Total expenses and other		9,251			21,708			(233	)		30,726

Income (loss) before income taxes	$	13,199		$	(4,287	)	$	-		$	8,912
Net Income (loss)		8,426			(3,082	)		-			5,344
Net loss attributable to noncontrolling interests		-			(954	)		-			(954	)
Net income (loss) attributable to Isramco		8,426			(2,128	)		-			6,298
Total Assets	$	60,984		$	45,758		$	-		$	106,742
Expenditures for Long-lived Assets	$	230		$	1,415		$	-		$	1,645

(in thousands)	Oil and Gas Exploration & Production			Production Services			Eliminations			Total
Six Months Ended June 30, 2018:
Sales revenues
United States	$	7,793		$	13,690		$	-		$	21,483
Israel		14,974			-			-			14,974
Intersegment revenues		-			88			(88	)		-
Gain on divestiture, office services and other		1,088			-			(60	)		1,028

Total revenues and other		23,855			13,778			(148	)		37,485

Operating costs and expenses		7,635			13,358			(148	)		20,845
Depreciation, depletion, and amortization		1,007			1,739			-			2,746
Interest expenses, net		234			2,316			-			2,550
Gain on derivative contracts		(1,148	)		-			-			(1,148	)
Other income, net		11			-			-			11

Total expenses and other		7,739			17,413			(148	)		25,004

Income (loss) before income taxes	$	16,116		$	(3,635	)	$	-		$	12,481
Net Income (loss)		11,907			(2,870	)		-			9,037
Net loss attributable to noncontrolling interests		-			(706	)		-			(706	)
Net income (loss) attributable to Isramco		11,907			(2,164	)		-			9,743
Total Assets	$	61,997		$	48,238		$	-		$	110,235
Expenditures for Long-lived Assets	$	241		$	4,678		$	-		$	4,919

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ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

THE FOLLOWING COMMENTARY SHOULD BE READ IN CONJUNCTION WITH THE CONSOLIDATED FINANCIAL STATEMENTS AND RELATED NOTES CONTAINED ELSEWHERE IN THIS REPORT ON FORM 10-Q. THE DISCUSSION CONTAINS FORWARD-LOOKING STATEMENTS THAT INVOLVE RISKS AND UNCERTAINTIES. THESE STATEMENTS RELATE TO FUTURE EVENTS OR OUR FUTURE FINANCIAL PERFORMANCE. IN SOME CASES, YOU CAN IDENTIFY THESE FORWARD-LOOKING STATEMENTS BY TERMINOLOGY SUCH AS “MAY,” “WILL,” “SHOULD,” “EXPECT,” “PLAN,” “ANTICIPATE,” “BELIEVE,” “ESTIMATE,” “PREDICT,” “POTENTIAL,” “INTEND,” OR “CONTINUE,” AND SIMILAR EXPRESSIONS. THESE STATEMENTS ARE ONLY PREDICTIONS. OUR ACTUAL RESULTS MAY DIFFER MATERIALLY FROM THOSE ANTICIPATED IN THESE FORWARD-LOOKING STATEMENTS AS A RESULT OF A VARIETY OF FACTORS, INCLUDING, BUT NOT LIMITED TO, THOSE SET FORTH UNDER “RISK FACTORS” AND ELSEWHERE IN THIS REPORT ON FORM 10-Q. ISRAMCO INC. DISCLAIMS ANY OBLIGATION TO UPDATE SUCH FORWARD LOOKING STATEMENTS.

Overview

Isramco is predominately an independent oil and natural gas company engaged in the exploration, development and production of oil and natural gas properties located onshore in the United States and ownership of various royalty interests in oil and gas concessions located offshore Israel. The Company also operates a production services company that provides well maintenance, workover services, well completion and recompletion services. Our properties are primarily located in Texas, New Mexico and Oklahoma. We also act as the operator of a certain number of these properties. Historically, we have grown through acquisitions, with a focus on properties within our core operating areas that we believe have significant development and exploration opportunities and where we can apply our technical experience and economies of scale to increase production and proved reserves, while lowering lease operating costs.

As noted above in Note 6 to the Company’s consolidated financial statements, in 2009 two natural gas discoveries known as “Tamar” and “Dalit” were made within the area covered by the Michal and Matan Licenses respectively and are known as the Tamar Field. In December 2009 the Israeli Petroleum Commissioner granted Noble Energy, Inc. (“Noble”) and its partners, Isramco Negev 2-LP, Delek Drilling, Avner Oil & Gas, and Dor Gas (the “Tamar Consortium”), two leases (the “Leases”). The Leases are scheduled to expire in December 2038. The Tamar Field is approximately 95 kilometers off the coast of the Israel in the Israel exclusive economic zone of the Eastern Mediterranean with a water depth of approximately 1,700 meters. On March 31, 2013, the Tamar Field began its initial production of the natural gas.

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Our financial results depend upon many factors, but are largely driven by the volume of our oil and natural gas production and the prices received for that production. Our production volumes will decline as reserves are depleted unless we expend capital in successful development and exploration activities or acquire additional properties with existing production. The amount we realize for our production depends predominantly upon commodity prices, which are affected by changes in market demand and supply, as impacted by overall economic activity, weather, pipeline capacity constraints, inventory storage levels, basis differentials and other factors, and secondarily upon our commodity price hedging activities. Accordingly, finding and developing oil and natural gas reserves at economical costs is critical to our long-term success. Our future drilling plans are subject to change based upon various factors, some of which are beyond our control, including drilling results, oil and natural gas prices, the availability and cost of capital, drilling and production costs, availability of drilling services and equipment, gathering system and pipeline transportation constraints and regulatory approvals. To the extent these factors lead to reductions in our drilling plans and associated capital budgets in future periods, our financial position, cash flows and operating results could be adversely impacted.

Proposed Merger Transaction

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Concentrations of Credit Risk

Liquidity and Capital Resources

Our primary source of cash during the six months ended June 30, 2019 was cash flow from operating activities. We continuously monitor our liquidity and evaluate our development plans in light of a variety of factors, including, but not limited to, our cash flows, capital resources and drilling success.

Our future capital resources and liquidity may depend, in part, on our success in developing the leasehold interests that we have acquired. Cash is required to fund capital expenditures necessary to offset inherent declines in production and proven reserves, which is typical in the capital-intensive oil and gas industry. Future success in growing reserves and production will be highly dependent on the capital resources available and our success in finding and acquiring additional reserves. Our production services subsidiary also requires capital resources to acquire and maintain equipment and continue growth. We expect to fund our future capital requirements through internally generated cash flows, borrowings under loans from related parties, and a future credit facility. Long-term cash flows are subject to a number of variables, including the level of production, prices, amount of work orders received, and our commodity price hedging activities, as well as various economic conditions that have historically affected the oil and natural gas industry.

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On May 18, 2015, the Company entered into a term loan credit agreement with Deutsche Bank Trust Company Americas (“Deutsche Bank”) in the amount of $120,000,000 secured by the Company’s interest in the Tamar Field. Interest on the borrowing is variable. The Company entered into interest rate swap agreements in relation to this borrowing. The terms of the agreement and swaps are disclosed in Notes 4 and 5 to the Company’s consolidated financial statements.

During the six months ended June 30, 2019, our cash increased by $1.1 million. Specifically, the net cash provided by operating activities of $13.7 million and proceeds from a related party loan of $0.6 million was offset by an investment of $1.6 million in production services equipment and oil and gas properties, $11.1 million in repayments of long term debt, and $0.5 million in repayments of short-term debt.

Debt:

	As of June 30,			As of December 31,
In thousands	2019			2018
Long – term debt net of discount and bank fees	$	47,183		$	56,193

Current maturities of long-term debt, short-term debt, current portion of discount and debt cost and bank overdraft		23,973			25,410
Total debt	$	71,156		$	81,603

Stockholders’ deficit	$	(2,025	)	$	(7,359	)

Debt to capital ratio		103	%		110	%

As of June 30, 2019, our total debt was $71,156,000, compared to total debt of $81,603,000 at December 31, 2018.

Contractual Obligations

Aggregate maturities of contractual obligations at June 30, 2019 are due in future years as follows (in thousands):

Principal Payments on Long-term debt:

2019	$	10,800
2020		17,100
2021		14,700
2022		14,400
2023		11,400
Total	$	68,400

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Cash Flow

Our primary source of cash during the six months ended June 30, 2019 was cash flow from operating activities. In the first six months of 2019, cash received from operations was primarily used for investments in production services equipment, oil and gas properties, and repayment of short term and long term loans. In the first six months of 2018, cash received from operations was primarily used for investments in production services equipment, oil and gas properties, and repayment of long term loans.

Operating cash flow fluctuations were substantially driven by changes in commodity prices and changes in our production volumes. Working capital was substantially influenced by these variables. Fluctuation in commodity prices and our overall cash flow may result in an increase or decrease in our future capital expenditures. Prices for oil and natural gas have historically been subject to seasonal fluctuations characterized by peak demand and higher prices in the winter heating season; however, the impact of other risks and uncertainties have influenced prices throughout recent years. See Results of Operations below for a review and summary of the impact of prices and volumes on sales.

	Six months Ended June 30,
	2019			2018
	(In thousands)
Cash flows provided by operating activities	$	13,736		$	5,159
Cash flows used in investing activities		(1,617	)		(4,464	)
Cash flows used in financing activities		(10,993	)		(8,045	)
Net increase (decrease) in cash, cash equivalents and restricted cash	$	1,126		$	(7,350	)

Operating Activities. During the six months ended June 30, 2019, compared to the same period in 2018, net cash flow provided by operating activities increased by $8,577,000 to $13,736,000. The increase was primarily attributable to collection of accounts receivable and other increases in working capital for the six months ended June 30, 2019 as compared to the same period in 2018. These increases in net cash flow provided by operating activities were partially offset by decreased revenues from our oil and gas exploration and production segment.

Investing Activities. Net cash flows used in investing activities for the six months ended June 30, 2019 and 2018 were $1,617,000 and $4,464,000, respectively. During the first six months of 2019, the Company invested $1,645,000, consisting of $230,000 for oil and gas properties and $1,415,000 in production services equipment. During the first six months of 2018, the Company invested $4,919,000, consisting of $241,000 for oil and gas properties and $4,678,000 in production services equipment. The Company also received cash proceeds of $455,000 from divestiture of oil and gas properties and sales of equipment.

Financing Activities. Net cash flows used in financing activities were $10,993,000 and $8,045,000 for the six months ended June 30, 2019 and 2018, respectively. During the first six months of 2019 the Company made payments on long term debt of $11,100,000, made payments on short term debt in the amount of $483,000. During the first six months of 2018 the Company made payments on long term debt of $7,800,000, made payments on short term debt in the amount of $343,000, and increased bank overdraft by $98,000.

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Results of Operations

Three Months Ended June 30, 2019 Compared to Three Months Ended June 30, 2018

Selected Data
	Three Months Ended June 30,
	2019			2018
	(In thousands except per share and BOE amounts)
Financial Results
Oil and Gas sales
United States	$	3,127		$	4,018
Israel		7,411			7,765
Production Services		7,816			7,927
Gain on divestiture		-			-
Other		268			282
Total revenues and other		18,622			19,992

Cost and expenses		13,758			12,762
Other expenses		1,449			1,061
Income tax expense		1,705			1,786
Net income attributable to common shareholders		1,710			4,383
Net loss attributable to non-controlling interests		(557	)		(325	)
Net income attributable to Isramco		2,267			4,708
Earnings per common share – basic	$	0.83		$	1.73
Earnings per common share – diluted	$	0.83		$	1.73

Weighted average number of shares outstanding- basic		2,717,648			2,717,648
Weighted average number of shares outstanding- diluted		2,717,648			2,717,648

Operating Results
Adjusted EBITDAX (1)	$	6,560		$	8,777
Sales volumes United States (MBOE)		93			108
Sales volumes Israel (MBOE)		224			238

Average cost per BOE United States: (2)
Production (excluding transportation and taxes)	$	20.61		$	17.86
General and administrative (oil and gas production segment)	$	21.35		$	10.36
Depletion	$	3.75		$	4.97

(1)	See Adjusted EBITDAX for a description of Adjusted EBITDAX, which is not a Generally Accepted Accounting Principles (GAAP) measure, and a reconciliation of Adjusted EBITDAX to income from operations before income taxes, which is presented in accordance with GAAP.

(2)	There are no costs associated with revenues from Israeli operations since the Company owns an overriding royalty in the Tamar Field, which is free of operating expenses.

Financial Results

Net income in the second quarter of 2019 was $2,267,000 or $0.83 per share. This compares to net income in the second quarter of 2018, which was $4,708,000 or $1.73 per share.

The Net income decreased by $2,441,000 compared to previous year period primarily due to a decrease in revenues from our oil and gas sales and production services along with an increase in operating expenses.

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Revenues, Volumes and Average Prices Oil and Gas Segment - Israel

During the three months ended June 30, 2019 the Tamar Field net sales applicable to Isramco amounted to 1,335,358 Mcf of natural gas and 1,719 Bbl of condensate with prices of $5.51 per Mcf and $58.59 per Bbl of condensate. Total revenues net of marketing and transportations expenses were $7,411,000.

During the three months ended June 30, 2018 the Tamar Field net sales applicable to Isramco amounted to 1,414,117 Mcf of natural gas and 1,823 Bbl of condensate with prices of $5.43 per Mcf and $67.57 per Bbl of condensate. Total revenues net of marketing and transportations expenses were $7,765,000.

Revenues, Volumes and Average Prices Oil and Gas Segment – United States

Sales Revenues

	Three Months Ended June 30,
In thousands except percentages	2019		2018		Δ vs. 2018
Gas sales	$	495	$	689		(28	)%
Oil sales		2,426		2,941		(18	)
Natural gas liquid sales		206		388		(47	)
Total	$	3,127	$	4,018		(22	)%

The Company’s sales revenues from U.S. based oil and gas operations for the second quarter of 2019 decreased by 22% when compared to same period in 2018 due to lower prices received for natural gas, crude oil and NGLs and lower sales volumes of natural gas, crude oil and NGLs.

Volumes and Average Prices

	Three Months Ended June 30,
	2019		2018		Δ vs. 2018
Natural Gas
Sales volumes Mmcf		247.90		284.5		(13	)%
Average Price per Mcf	$	2.00	$	2.42		(17	)
Total gas sales revenues (thousands)	$	495	$	689		(28	)%

Crude Oil
Sales volumes MBbl		41.21		45.6		(10	)%
Average Price per Bbl	$	58.87	$	64.49		(9	)
Total oil sales revenues (thousands)	$	2,426	$	2,941		(18	)%

Natural gas liquids
Sales volumes MBbl		10.76		15.1		(29	)%
Average Price per Bbl	$	19.14	$	25.64		(25	)
Total natural gas liquids sales revenues (thousands)	$	206	$	388		(47	)%

In the United States the Company’s natural gas sales volumes decreased by 13%, crude oil sales volumes decreased by 10%, and natural gas liquids sales volumes decreased by 29% for the second quarter of 2019 compared to the same period of 2018.

The Company’s average natural gas price received for the second quarter of 2019 decreased by 17%, or $0.42 per Mcf, when compared to the same period of 2018. The Company’s average crude oil price for the second quarter of 2019 decreased by 9%, or $5.62 per Bbl, when compared to the same period of 2018. Our average natural gas liquids price for the second quarter of 2019 decreased by 25%, or $6.50 per Bbl, when compared to the same period of 2018.

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Analysis of Oil and Gas Operations Sales Revenues

The following table provides a summary of the effects of changes in volumes and prices on Isramco’s United States sales revenues for the three months ended June 30, 2019 compared to the same period of 2018.

In thousands	Natural Gas			Oil			Natural gas liquids
2018 sales revenues	$	689		$	2,941		$	388
Changes associated with sales volumes		(89	)		(284	)		(112	)
Changes in prices		(105	)		(231	)		(70	)
2019 sales revenues	$	495		$	2,426		$	206

Operating Expenses (excluding production services segment)

	Three Months Ended June 30,
In thousands except percentages	2019			2018		Δ vs. 2018
Lease operating expense, transportation and taxes	$	2,257		$	2,360		(4	)%
Depreciation, depletion and amortization of oil and gas properties		350			537		(35	)
Accretion expense		219			228		(4	)
Loss from plugging and abandonment of wells		(49	)		154		(132	)
General and administrative		1,992			1,120		78
	$	4,769		$	4,399		8	%

During the three months ended June 30, 2019, our operating expenses increased by 8% when compared to the same period of 2018 due to the following factors:

●	Lease operating expense, transportation cost and taxes decreased by 4%, or $103,000, in 2019 when compared to 2018. On a per unit basis, lease operating expenses (excluding transportation and taxes) increased by $2.75 per MBOE to $20.61 per MBOE in 2019 from $17.86 per MBOE in 2018.

●

Depreciation, Depletion & Amortization (“DD&A”) of the cost of proved oil and gas properties is calculated using the unit-of-production method. Our DD&A rate and expense are the composite of numerous individual field calculations. There are several factors that can impact our composite DD&A rate and expense including, but not limited to, field production profiles, drilling or acquisition of new wells, disposition of existing wells, and reserve revisions (upward or downward) primarily related to well performance and commodity prices, and impairments. Changes in these factors may cause our composite DD&A rate and expense to fluctuate from period to period. DD&A decreased by 35%, or $187,000 in 2019 when compared to 2018 primarily due to lower production and a lower depletable base used to calculate DD&A. On a per unit basis, depletion expense decreased by $1.22 per MBOE to $3.75 per MBOE in 2019 from $4.97 per BOE in 2018.

●

The increase in general and administrative expenses was primarily due to an increase in legal and other professional fees associated with upcoming merger, primarily related to the proposed Merger transaction as disclosed in the Company’s Current Report on Form 8-K filed with the SEC on May 20, 2019, Preliminary Proxy Statement filed with the SEC on August 1, 2019, and Schedule 13E-3 filed with the SEC on August 1, 2019.

Production Services Segment

	Three Months Ended June 30,
In thousands except percentages	2019			2018			Δ vs. 2018
Production Services*	$	7,816		$	8,015			(2	)%
Operating expenses*		7,819			7,448			5
Depreciation		1,023			918			11
General and administrative*		176			115			53
Operating loss	$	(1,202	)	$	(466	)		158	%
*Includes intersegment revenues and expenses.

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●	Our sales revenues from production services operations for the second quarter of 2019 decreased by 2% or $199,000 when compared to same period in 2018 as a result of a shortage in skilled workforce.

●	Operating expenses from production services operations for the second quarter of 2019 increased by 5% or $371,000 when compared to the same period in 2018 as a result of increased operational expenditures.

●

Production service equipment depreciation – the amounts represent depreciation of production service rigs and auxiliary equipment for our production services subsidiary. The depreciation expenses for the second quarter of 2019 totaled $1,023,000, an increase of $105,000 compared to the same period in 2018. This increase in depreciation is primarily a result of additional equipment purchases.

●	General and administrative expenses from production services operations for the second quarter of 2019 totaled $176,000, an increase of $61,000 compared to the same period in 2018 as a result of increased legal fees and other professional fees.

Other expenses

	Three Months Ended June 30,
In thousands except percentages	2019		2018			Δ vs. 2018
Interest expense, net	$	933	$	1,333			(30	)%
Loss (gain) on interest rate swap		513		(283	)		(281	)
Capital loss		3		11			(73	)
	$	1,449	$	1,061			(37	)%

Interest expense. Isramco’s interest expense decreased by 30%, or $400,000, for the three months ended June 30, 2019 compared to the same period of 2018. This decrease was primarily due to lower interest rate and principal balances outstanding during the second quarter of 2019 compared to 2018.

Unrealized loss (gain) on interest rate swaps. For the second quarter of 2019 we recorded a loss as a result of changes in fair value of the derivative in the amount of $513,000, comprised of a cash settlement gain of $107,000 and loss of $620,000 as a result of changes in the fair value. For the second quarter of 2018 we recorded a gain as a result of changes in fair value of the derivative in the amount of $283,000, comprised of a cash settlement loss of $125,000 and gain of $408,000 as a result of changes in the fair value of the divestiture.

Adjusted EBITDAX.

To assess the operating results of Isramco, management analyzes income from operations before income taxes, interest expense, exploration expense, unrealized gain (loss) on derivative contracts and DD&A expense and impairments (“Adjusted EBITDAX”). Adjusted EBITDAX is not a GAAP measure. Isramco’s definition of Adjusted EBITDAX excludes exploration expense because exploration expense is not an indicator of operating efficiency for a given reporting period, but rather is monitored by management as a part of the costs incurred in exploration and development activities. Similarly, Isramco excludes DD&A expense and impairments from Adjusted EBITDAX as a measure of segment operating performance because capital expenditures are evaluated at the time capital costs are incurred. The Company’s definition of Adjusted EBITDAX also excludes interest expense to allow for assessment of segment operating results without regard to Isramco’s financing methods or capital structure. The company believes that adjusted EBITDAX is a widely accepted financial indicator of a company’s ability to incur and service debt, fund capital expenditures and make payments on its long-term loans. Management believes that the presentation of Adjusted EBITDAX provides information useful in assessing the Company’s financial condition and results of operations.

However, Adjusted EBITDAX, as defined by Isramco, may not be comparable to similarly titled measures used by other companies. Therefore, Isramco’s consolidated Adjusted EBITDAX should be considered in conjunction with income (loss) from operations and other performance measures prepared in accordance with GAAP, such as operating income or cash flow from operating activities. Adjusted EBITDAX has important limitations as an analytical tool because it excludes certain items that affect income from continuing operations and net cash provided by operating activities. Adjusted EBITDAX should not be considered in isolation or as a substitute for an analysis of Isramco’s results as reported under GAAP. Below is a reconciliation of consolidated Adjusted EBITDAX to income (loss) from operations before income taxes.

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	Three Months Ended June 30,
In thousands except percentages	2019		2018
Income from operations before income taxes	$	3,415	$	6,169
Depreciation, depletion and amortization expense		1,373		1,455
Interest expense		933		1,333
Unrealized loss on interest rate swap		620		(408	)
Accretion expense		219		228
Consolidated Adjusted EBITDAX	$	6,560	$	8,777

Results of Operations

Six Months Ended June 30, 2019 Compared to Six Months Ended June 30, 2018

Selected Data
	Six Months Ended June 30,
	2019			2018
	(In thousands except per share and BOE amounts)
Financial Results
Oil and Gas sales
United States	$	6,344		$	7,793
Israel		15,512			14,974
Production Services		17,248			13,690
Gain on divestiture		-			472
Other		534			556
Total revenues and other		39,638			37,485

Cost and expenses		27,762			23,591
Other expenses		2,964			1,413
Income tax expense		3,568			3,444
Net income attributable to common shareholders		5,344			9,037
Net loss attributable to non-controlling interests		(954	)		(706	)
Net income attributable to Isramco		6,298			9,743
Earnings per common share – basic	$	2.32		$	3.59
Earnings per common share – diluted	$	2.32		$	3.59

Weighted average number of shares outstanding- basic		2,717,648			2,717,648
Weighted average number of shares outstanding- diluted		2,717,648			2,717,648

Operating Results
Adjusted EBITDAX (1)	$	15,157		$	16,768
Sales volumes United States (MBOE)		200			208
Sales volumes Israel (MBOE)		468			459

Average cost per BOE United States: (2)
Production (excluding transportation and taxes)	$	19.60		$	18.09
General and administrative (oil and gas production segment)	$	16.71		$	11.06
Depletion	$	3.67		$	4.83

(1)	See Adjusted EBITDAX for a description of Adjusted EBITDAX, which is not a Generally Accepted Accounting Principles (GAAP) measure, and a reconciliation of Adjusted EBITDAX to income from operations before income taxes, which is presented in accordance with GAAP.

(2)	There are no costs associated with revenues from Israeli operations since the Company owns overriding royalty in the Tamar Field which is free of operating expenses.

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Financial Results

Net income in the six months ended June 30, 2019 was $6,298,000 or $2.32 per share. This compares to net income of $9,743,000 or $3.59 per share, for the same period of 2018.

This decrease in net income was primarily due to a loss on derivative contracts of $846,000 in the first six months of 2019 compared to a gain on derivative contracts of $1,148,000 for the same period in 2018, increases in operating expenses, decreases in revenues from our US based oil and gas operations and decreases in amounts received as a result of divestitures of oil and gas properties. These were offset by increased revenues from the production services segment and revenues from the Tamar Royalty.

Revenues, Volumes and Average Prices Oil and Gas Segment - Israel

Revenues, Volumes and Average Prices Oil and Gas Segment – United States

Sales Revenues

	Six Months Ended June 30,
In thousands except percentages	2019		2018		Δ vs. 2018
Gas sales	$	1,128	$	1,439		(22	)%
Oil sales		4,721		5,610		(16	)
Natural gas liquid sales		495		744		(33	)
Total	$	6,344	$	7,793		(19	)%

The Company’s sales revenues from United States based oil and gas operations for the six month period ending June 30, 2019 decreased by 19% when compared to same period in 2018 due to lower prices received for natural gas, crude oil and NGLs and lower production volumes of oil, natural gas, and NGLs.

Volumes and Average Prices

	Six Months Ended June 30,
	2019		2018		Δ vs. 2018
Natural Gas
Sales volumes Mmcf		523		547		(4	)%
Average Price per Mcf	$	2.16	$	2.63		(18	)
Total gas sales revenues (thousands)	$	1,128	$	1,439		(22	)%

Crude Oil
Sales volumes MBbl		86		89		(3	)%
Average Price per Bbl	$	54.84	$	63.30		(13	)
Total oil sales revenues (thousands)	$	4,721	$	5,610		(16	)%

Natural gas liquids
Sales volumes MBbl		27		29		(7	)%
Average Price per Bbl	$	18.50	$	25.95		(29	)
Total natural gas liquids sales revenues (thousands)	$	495	$	744		(33	)%

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In the United States the Company’s natural gas sales volumes decreased by 4%, crude oil sales volumes decreased by 3%, and natural gas liquids sales volumes decreased by 7% for the first six months of 2019 compared to the same period of 2018.

The Company’s average natural gas price received for the first six months of 2019 decreased by 18%, or $0.47 per Mcf, when compared to the same period of 2018. The Company’s average crude oil price for the first six months of 2019 decreased by 13%, or $8.46 per Bbl, when compared to the same period of 2018. Our average natural gas liquids price for the first six months of 2019 decreased by 29%, or $7.45 per Bbl, when compared to the same period of 2018.

Analysis of Oil and Gas Operations Sales Revenues

The following table provides a summary of the effects of changes in volumes and prices on Isramco’s United States sales revenues for the six months ended June 30, 2019 compared to the same period of 2018.

In thousands	Natural Gas			Oil			Natural gas liquids
2018 sales revenues	$	1,439		$	5,610		$	744
Changes associated with sales volumes		(63	)		(161	)		(50	)
Changes in prices		(248	)		(728	)		(199	)
2019 sales revenues	$	1,128		$	4,721		$	495

Operating Expenses (excluding production services segment)

	Six Months Ended June 30,
In thousands except percentages	2019		2018		Δ vs. 2018
Lease operating expense, transportation and taxes	$	4,686	$	4,660		1	%
Depreciation, depletion and amortization of oil and gas properties		735		1,007		(27	)
Accretion expense		434		458		(5	)
Loss (gain) from plugging and abandonment of wells		13		212		(94	)
General and administrative		3,342		2,306		45
	$	9,210	$	8,643		7	%

During the six months ended June 30, 2019, our operating expenses increased by 7% when compared to the same period of 2018 due to the following factors:

●	Lease operating expense, transportation cost and taxes increased by 1%, or $26,000 in 2019 when compared to 2018. On a per unit basis, lease operating expenses (excluding transportation and taxes) increased by $1.57 per MBOE to $19.60 per MBOE in 2019 from $18.03 per MBOE in 2018.

●

Depreciation, Depletion & Amortization (“DD&A”) of the cost of proved oil and gas properties is calculated using the unit-of-production method. Our DD&A rate and expense are the composite of numerous individual field calculations. There are several factors that can impact our composite DD&A rate and expense including, but not limited to, field production profiles, drilling or acquisition of new wells, disposition of existing wells, and reserve revisions (upward or downward) primarily related to well performance and commodity prices, and impairments. Changes in these factors may cause our composite DD&A rate and expense to fluctuate from period to period. DD&A decreased by 27%, or $272,000 in 2019 when compared to the same period 2018 primarily due to lower production and a lower depletable base used to calculate DD&A. On a per unit basis, depletion expense decreased by $1.16 per MBOE to $3.67 per MBOE in 2019 from $4.83 per MBOE in 2018.

●	The loss from plugging and abandonment of wells is related to plugging operations from non-operated properties.

●

The increase in general and administrative expenses was primarily due to an increase in legal and other professional fees, primarily related to the proposed Merger transaction as disclosed in the Company’s Current Report on Form 8-K filed with the SEC on May 20, 2019, Preliminary Proxy Statement filed with the SEC on August 1, 2019, and Schedule 13E-3 filed with the SEC on August 1, 2019.

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Production Services Segment

	Six Months Ended June 30,
In thousands except percentages	2019			2018			Δ vs. 2018
Production Services*	$	17,421		$	13,778			26	%
Operating expenses*		16,506			13,033			27
Depreciation		1,968			1,739			13
General and administrative*		310			324			(4	)
Operating loss	$	(1,363	)	$	(1,318	)		3	%
*Includes intersegment revenues and expenses.

●	Our sales revenues from production services operations for the first six months of 2019 increased by 26% or $3,643,000 when compared to same period in 2018 as a result of increased demand for our services and related expansion in the market.

●	Operating expenses from production services operations for the first six months of 2019 increased by 27% or $3,473,000 when compared to the same period in 2018 as a result of increased operations and related payroll.

●

Production service equipment depreciation – the amounts represent depreciation of production services rigs and auxiliary equipment for our production services subsidiary. The depreciation expenses for the first six months of 2019 totaled $1,968,000, an increase of $229,000 compared to the same period in 2019 as a result of the purchase of new equipment.

●	General and administrative expenses from production services operations for the first six months of 2019 decreased to $310,000, compared to $324,000 for the same period in 2018 primarily as a result of decreased legal fees for production services operations.

Other expenses

	Six Months Ended June 30,
In thousands except percentages	2019		2018			Δ vs. 2018
Interest expense, net	$	2,117	$	2,550			(17	)%
Loss (gain) on interest rate swap		846		(1,148	)		(174	)
Capital loss		1		11			(91	)
	$	2,964	$	1,413			110	%

Interest expense. Isramco’s interest expense decreased by 17%, or $433,000 for the six months ended June 30, 2019 compared to the same period of 2018. This decrease was primarily due to a lower interest rates during the first six months of 2019 compared to 2018 and lower outstanding principal for the period.

Loss on interest rate swap. During the first six months of 2019 we recorded a loss as a result of changes in fair value of the derivative in the amount of $991,000 and receipt from cash settlements of $145,000. In 2018 we recorded a gain as a result of changes in fair value of the derivative in the amount of $1,467,000 and cash settlements of $319,000.

Adjusted EBITDAX.

To assess the operating results of Isramco, management analyzes income from operations before income taxes, interest expense, exploration expense, unrealized gain (loss) on derivative contracts and DD&A expense and impairments (“Adjusted EBITDAX”). Adjusted EBITDAX is not a GAAP measure. Isramco’s definition of Adjusted EBITDAX excludes exploration expense because exploration expense is not an indicator of operating efficiency for a given reporting period, but rather is monitored by management as a part of the costs incurred in exploration and development activities. Similarly, Isramco excludes DD&A expense and impairments from Adjusted EBITDAX as a measure of segment operating performance because capital expenditures are evaluated at the time capital costs are incurred. The Company’s definition of Adjusted EBITDAX also excludes interest expense to allow for assessment of segment operating results without regard to Isramco’s financing methods or capital structure. The Company believes that adjusted EBITDAX is a widely accepted financial indicator of a company’s ability to incur and service debt, fund capital expenditures and make payments on its long term loans. Management believes that the presentation of Adjusted EBITDAX provides information useful in assessing the Company’s financial condition and results of operations.

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	Six Months Ended June 30,
In thousands except percentages	2019		2018
Income from operations before income taxes	$	8,912	$	12,481
Depreciation, depletion and amortization expense		2,703		2,746
Interest expense		2,117		2,550
Unrealized loss (gain) on interest rate swap		991		(1,467	)
Accretion expense		434		458
Consolidated Adjusted EBITDAX	$	15,157	$	16,768

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ITEM 3. Quantitative and Qualitative Disclosures about Market Risk

Derivative Instruments and Hedging Activity

We are exposed to various risks, including risks associated with energy commodity price. If oil and natural gas prices decline significantly, our ability to finance our capital budget and operations could be adversely impacted. We expect energy prices to remain volatile and unpredictable, therefore we have adopted a risk management policy which allows for the use of derivative instruments to provide partial protection against declines in oil and natural gas prices by reducing the risk of price volatility and the affect it could have on our operations. The type of derivative instrument that we typically utilize is swaps. The total volumes which we hedge through the use of our derivative instruments vary from period to period. Currently, we have no open positions or contracts in place in relation to commodity prices.

When such contracts are in place, we are exposed to market risk on our open derivative contracts and counterparty performance risk with respect to our counterparties. However, we usually do not expect such non-performance because our contracts are usually with major financial institutions with investment grade credit ratings.

We are also exposed to interest rate risk on our variable interest rate debt. If interest rates increase, our interest expense would increase and our available cash flow would decrease. We continue to monitor our risk exposure as we incur future indebtedness at variable interest rates and will look to continue our risk management policy as situations present themselves. Periodically, we look to utilize interest rate swaps to reduce the exposure to market rate fluctuations by converting variable interest rates to fixed interest rates.

We account for our derivative activities under the provisions of ASC 815, Derivatives and Hedging (ASC 815). ASC 815 establishes accounting and reporting that every derivative instrument be recorded on the balance sheet as either an asset or liability measured at fair value. The Company has elected not to designate any of its positions for hedge accounting. See Item 1. Consolidated Financial Statements.

ITEM 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures.

In accordance with Exchange Act Rule 13a-15 and 15d-15, we carried out an evaluation, under the supervision and with the participation of management, including our Co-Chief Executive Officers, our Chief Financial Officer, and our Chief Accounting Officer, of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, our Co-Chief Executive Officer, Chief Financial Officer, and Chief Accounting Officer concluded that our disclosure controls and procedures were effective as of June 30, 2019 to provide reasonable assurance that information required to be disclosed in our reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms. Our disclosure controls and procedures include controls and procedures designed to ensure that information required to be disclosed in reports filed or submitted under the Exchange Act is accumulated and communicated to our management, including our Chief Executive Officer, Chief Financial Officer and Chief Accounting Officer as appropriate, to allow timely decisions regarding required disclosure.

There were no changes in the Company’s internal control over financial reporting that occurred during the most recent fiscal quarter that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

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PART II - Other Information

ITEM 1. Legal Proceedings

As noted above, the Company owns an overriding royalty interest of 1.5375% in the Tamar Field, which will increase to 2.7375% after payout (the “Tamar Royalty”). With regard to the payout of the Tamar Field, disagreements between the Company and Isramco Negev 2 Limited Partnership have emerged as to what costs should be included in the calculation of payout. The disagreements primarily stem from the fact that the agreements governing the creation of the Tamar Royalty were formulated in the 1980s and do not have a clear and unequivocal definition as to what costs should be included in the payout calculation. In addition to actual costs for the development of the Tamar Field, Isramco, Negev 2 Limited Partnership has asserted that the following costs should be included in the calculation of payout: (i) Isramco Negev 2 Limited Partnership’s financing costs; (ii) the general and administrative expenses of Isramco Negev 2 Limited Partnership; (iii) the expected decommissioning costs of the Tamar Field; and (iv) expected future payments to be made in respect of the “Sheshinsky Levy” under Israeli law. In addition to the claim asserted by Isramco Negev 2 Limited Partnership, the Company has asserted counterclaims related to Isramco Negev 2 Limited Partnership’s inclusion into the payout calculation of charges related to gathering and transportation infrastructure. At the time of initiating arbitration, the Company believed that the total scope of the claim asserted by Isramco Negev 2 Limited Partnership was approximately forty-five million dollars ($45,000,000); however, this amount increases each month based on Isramco Negev 2 Limited Partnership’s failure to pay the increased, post-payout overriding royalty to the Company. In addition, certain claims and the counterclaims asserted by the Company related to post production costs and pipeline infrastructure have not been quantified. Under the terms of the agreements creating the Tamar Royalty, the dispute is subject to arbitration in Israel. The Company believes that the claims of Isramco Negev 2 Limited Partnership are erroneous and contrary to generally accepted industry practice. The Company expects that the matter will be favorably resolved through this arbitration process; however, the Company cannot be assured of a favorable result in this arbitration process. Accordingly, the Company continues to receive royalty payments at the lower rates as if the Investment Repayment Date has not occurred. On February 26, 2017, Isramco Negev 2 Limited Partnership reported the dispute concerning the Tamar Royalty in its filing with the stock exchange in Israel. As noted above, this dispute will be resolved through arbitration proceedings. The Company and Isramco Negev 2-LP have arranged to conduct the arbitration through the Center for Arbitration and Dispute Resolution (CADR) in Israel and have agreed upon the appointment of retired judge Itzhak Inbar to preside over the proceeding. The preliminary arbitration hearing in the matter occurred on August 13, 2017. On February 25, 2018, the Company submitted as Statement of Claim outlining the Company’s position with regard to the matter. Currently, the case is in its early stages with the parties expected to complete the discovery process in the coming months. The Company expects the discovery and evidentiary filings in the matter to conclude in 2019, with evidentiary hearings to occur in February of 2020. The Company believes that its interpretation of the agreements governing the creation of the Tamar Royalty is the correct interpretation and, accordingly, intends to vigorously pursue its case in the aforementioned arbitration proceedings.

ITEM 1A. Risk Factors

None

ITEM 2. Change in Securities & Use of Proceeds

None

ITEM 3. Default Upon Senior Securities

None

ITEM 4. Removed and Reserved

None

ITEM 5. Other Information

None

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ITEM 6. Exhibits

Exhibits
2.1	Agreement and Plan of Merger, dated as of May 20, 2019, by and Naphtha Israel Petroleum Corporation Ltd., Naphtha Holding Ltd., I.O.C. – Israel Oil Company, Ltd., Naphtha US Oil, Inc. and Isramco, Inc.*
10.1	Voting and Support Agreement, dated as of May 20, 2019, by and among Naphtha Holding Ltd., I.O.C. – Israel Oil Company, Ltd., Haim Tsuff and Isramco, Inc.*
10.2	Form of Indemnification Agreement*
31.1	Certification of Chief Executive Officer pursuant to Section 31 2 of Sarbanes-Oxley Act
31.2	Certification of Chief Financial Officer pursuant to Section 31 2 of Sarbanes-Oxley Act
31.3	Certification of Chief Accounting Officer pursuant to Section 31 2 of Sarbanes-Oxley Act
32.1	Certification of Chief Executive and Principal Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 Of the Sarbanes-Oxley act of 2002
32.2	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 Of the Sarbanes-Oxley act of 2002
32.3	Certification of Chief Accounting Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 Of the Sarbanes-Oxley act of 2002
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema
101.CAL	XBRL Taxonomy Extension Calculation Linkbase
101.DEF	XBRL Taxonomy Extension Definition Linkbase
101.LAB	XBRL Taxonomy Extension Label Linkbase
101.PRE	XBRL Taxonomy Extension Presentation Linkbase

*Incorporated by reference to the Company’s Current Report on Form 8-K filed with the SEC on May 20, 2019.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	ISRAMCO, INC

Date: AUGUST 9, 2019	By:	/s/ HAIM TSUFF
		HAIM TSUFF
		CO-CHIEF EXECUTIVE OFFICER
		(PRINCIPAL EXECUTIVE OFFICER)

Date: AUGUST 9, 2019	By:	/s/ EDY FRANCIS
		EDY FRANCIS
		CO-CHIEF EXECUTIVE OFFICER & CHIEF FINANCIAL OFFICER
		(PRINCIPAL FINANCIAL OFFICER)

Date: AUGUST 9, 2019	By:	/s/ ZEEV KOLTOVSKOY
		ZEEV KOLTOVSKOY
		CHIEF ACCOUNTING OFFICER
		(PRINCIPAL ACCOUNTING OFFICER)