UNITED STATES SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

_____________________

FORM 10-Q

_____________________

☒ Quarterly Report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934.

For the quarterly period ended ~~June~~September 30, 2016

☐ Transition Report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934.

For the transition period from ___________________ to _______________________

Commission File Number 33-16820-D

ARÊTE INDUSTRIES, INC.

(Exact name of registrant as specified in its charter)

Colorado	84-1508638
(State or Other Jurisdiction of Incorporation or Organization)	(I.R.S. Employer Identification No.)

7260 Osceola Street, Westminster, Colorado 80030

(Address of Principal Executive Offices) (Zip Code)

303-427-8688

(Registrant's Telephone Number, Including Area Code)

Indicate by check mark whether the registrant (1) has 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 and posted on its corporate Web site, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ☒ X No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See definitions of "large accelerated filer", "accelerated filer" and "smaller reporting 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 of 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 ~~February~~May 612, 2017, the Registrant had 14,642,080 shares of common stock issued and outstanding.

ARÊTE INDUSTRIES, INC.

Table of Contents

Page Part 1 - Financial Information 3 Item 1 - Financial Statements 3 Item 2 - Management's Discussion and Analysis of Financial Condition and Results of Operations 1613 Item 3 - Quantitative and Qualitative Disclosures about Market Risk 2118 Item 4 - Controls and Procedures 2119 Part 2 - Other Information 2219 Item 1 - Legal Proceedings 2219 Item 1A - Risk Factors 2219 Item 2 - Sales of Unregistered Equity Securities and Use of Proceeds 2219 Item 3 - Defaults upon Senior Securities 2219 Item 4 - Mine Safety Disclosures 2219 Item 5 - Other Information 2219 Item 6 – Exhibits 2320 Signatures 2421

Part 1 – Financial Information

Item 1 - Financial Statements

ARÊTE INDUSTRIES, INC.
CONDENSED BALANCE SHEETS (Unaudited)
	As of
	June 30,			December 31,
	September 30,			December 31,
ASSETS	2016			2015
Current Assets:
Cash	$	~~265~~259,~~778~~340		$	521,666
Accounts receivable - oil and gas sales		2018,~~960~~581			2,539
Subscription receivable		-			105,000
Prepaid expenses and other		2511,~~345~~832			32,554
Total Current Assets		~~312~~289,~~083~~753			661,759
Property and Equipment:
Oil and gas properties, at cost, successful efforts method:
Proved properties		8,431,505			8,683,273
Unproved properties		154,977			154,836
Furniture and equipment		22,522			22,522
Total property and equipment		8,609,004			8,860,631
Less accumulated depreciation, depletion and amortization		(3,~~496~~573,522	)		(3,245,522	)
Net Property and Equipment		5,~~112~~035,482			5,615,109
TOTAL ASSETS	$	5,~~424~~325,~~565~~235		$	6,276,868

The Accompanying Notes are an Integral Part of These Financial Statements

ARÊTE INDUSTRIES, INC. CONDENSED BALANCE SHEETS, Continued (Unaudited)

ARÊTE INDUSTRIES, INC.
CONDENSED BALANCE SHEETS, Continued (Unaudited)

	As of
	September 30,			December 31,
LIABILITIES AND STOCKHOLDERS' EQUITY	2016			2015
Current Liabilities:
Accounts payable:
Trade accounts payable		143,197			64,896
Accounts payable - DNR Oil & Gas, Inc.		367,504			501,281
Accounts payable - directors and affiliates		53,398			-
Dividends payable:
Dividends payable		5,999			-
Dividends payable - directors and affiliates		41,992			-
Accrued interest expense:
Accrued interest expense		3,983			2,532
Accrued interest expense - directors and affiliates		16,374			9,442
Notes and advances payable - current portion:
Notes and advances payable		81,502			989,853
Notes and advances payable - directors and affiliates		134,595			13,152
Current portion of asset retirement obligations		426,600			409,621
Other accrued costs and expenses		61,745			68,577
Total Current Liabilities		1,336,889			2,059,354
Long-Term Liabilities:
Notes and advances payable, net of current portion:
Notes and advances payable, net of discount		1,198,439			173,519
Notes and advances payable - Directors and affiliates		20,057			151,379
Asset retirement obligations, net of current portion		639,400			585,576
Total Long-Term Liabilities		1,857,896			910,474
Total Liabilities		3,194,785			2,969,828
Commitments and Contingencies (Notes 6, 7, 8 and 9)
Stockholders' Equity:
Convertible Class A preferred stock; $10,000 face value per share, authorized 1,000,000 shares:
Series 1; 30,000 shares authorized, none issued and outstanding.		-			-
Series 2; authorized 2,500 shares, 272 and 267 shares issued and outstanding at September 30, 2016 and December 31, 2015, respectively, liquidation preference $2,767,991 at September 30, 2016.		2,720,000			2,670,000
Common stock, no par value; 499,000,000 shares authorized, 14,674,580 and 14,295,413 issued and outstanding at September 30, 2016 and December 31, 2015, respectively.		21,535,469			21,502,635
Accumulated deficit		(22,125,019	)		(20,865,595	)
Total Stockholders' Equity		2,130,450			3,307,040
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$	5,325,235		$	6,276,868

	As of
	June 30,			December 31,
LIABILITIES AND STOCKHOLDERS' EQUITY	2016			2015
Current Liabilities:
Accounts payable:
Trade accounts payable		130,987			64,896
Accounts payable - DNR Oil & Gas, Inc.		267,259			501,281
Accounts payable - directors and affiliates		31,398			-
Dividends payable:
Dividends payable		5,934			-
Dividends payable - directors and affiliates		41,536			-
Accrued interest expense:
Accrued interest expense		2,630			2,532
Accrued interest expense - directors and affiliates		14,074			9,442
Notes and advances payable - current portion:
Notes and advances payable		253,854			989,853
Notes and advances payable - directors and affiliates		134,354			13,152
Current portion of asset retirement obligations		419,094			409,621
Other accrued costs and expenses		101,077			68,577
Total Current Liabilities		1,402,197			2,059,354
Long-Term Liabilities:
Notes and advances payable, net of current portion:
Notes and advances payable, net of discount		919,976			173,519
Notes and advances payable - Directors and affiliates		23,617			151,379
Asset retirement obligations, net of current portion		623,913			585,576
Total Long-Term Liabilities		1,567,506			910,474
Total Liabilities		2,969,703			2,969,828
Commitments and Contingencies (Notes 6, 7 and 8)
Stockholders' Equity:
Convertible Class A preferred stock; $10,000 face value per share, authorized 1,000,000 shares:
Series 1; 30,000 shares authorized, none issued and outstanding.		-			-
Series 2; authorized 2,500 shares, 272 and 267 shares issued and outstanding in 2016 and 2015, respectively, liquidation preference $2,767,470 at June 30, 2016.		2,720,000			2,670,000
Common stock, no par value; 499,000,000 shares authorized, 14,642,080 and 14,295,413 issued and outstanding at June 30, 2016 and December 31, 2015, respectively.		21,531,569			21,502,635
Accumulated deficit		(21,796,707	)		(20,865,595	)
Total Stockholders' Equity		2,454,862			3,307,040
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$	5,424,565		$	6,276,868
The Accompanying Notes are an Integral Part of These Financial Statements.

The Accompanying Notes are an Integral Part of These Financial Statements.

ARÊTE INDUSTRIES, INC. AND SUBSIDIARIES CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

ARÊTE INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED STATEMENTS OF OPERATIONS
(Unaudited)

	For the Three months Ended September 30,						For the Nine months Ended September 30,
	2016			2015			2016			2015
Revenues:
Oil sales	$	219,404		$	230,728		$	633,961		$	617,906
Natural gas sales		20,220			22,507			65,638			112,554
Royalty revenues		483			514			1,760			4,455
Sale of oil and natural gas properties		-			-			-			27,120
Total revenues		240,107			253,749			701,359			762,035
Operating Expenses:
Oil and gas producing activities:
Lease operating expenses		313,086			270,719			800,541			685,587
Production taxes		19,367			29,101			55,434			66,900
Depreciation, depletion, amortization and accretion		104,523			189,335			403,333			531,292
Impairment		-			-			252,000			-
Gas gathering:
Operating expenses		-			-			-			1,406
Depreciation		-			11,055			-			33,165
General and administrative expenses:
Director fees		10,000			13,333			30,000			35,333
Investor relations		1,097			30,897			8,410			41,525
Legal, auditing and professional fees		23,185			6,458			109,069			80,313
Consulting fees executive services-Related Parties		14,000			43,333			54,732			126,733
Other administrative expenses		10,103			20,699			33,275			65,138
Depreciation		-			143			-			428
Total operating expenses		495,361			615,073			1,746,794			1,667,820
Operating loss		(255,254	)		(361,324	)		(1,045,435	)		(905,785	)
Other expense
Interest expense net		(25,067	)		(28,372	)		(70,019	)		(87,052	)
Loss before income taxes		(280,321	)		(389,696	)		(1,115,454	)		(992,837	)
Income tax benefit (expense)		-			-			-			-
Net loss	$	(280,321	)	$	(389,696	)	$	(1,115,454	)	$	(992,837	)
Net Loss Applicable to Common Stockholders:
Net loss	$	(280,321	)	$	(389,696	)	$	(1,115,454	)	$	(992,837	)
Preferred stock dividends declared		(47,991	)		-			(143,970	)		-
Net loss applicable to common stockholders	$	(328,312	)	$	(389,696	)	$	(1,259,424	)	$	(992,837	)
Loss Per Share Applicable to Common Stockholders:
Basic	$	(0.02	)	$	(0.03	)	$	(0.09	)	$	(0.08	)

Diluted	$	(0.02	)	$	(0.03	)	$	(0.09	)	$	(0.08	)
Weighted Average Number of Common Shares Outstanding:
Basic		14,673,700			12,966,000			14,450,550			12,764,000

Diluted		14,673,700			12,966,000			14,450,550			12,764,000

	For the Three months Ended June 30,						For the Six months Ended June 30,
	2016			2015			2016			2015
Revenues:
Oil sales	$	260,574		$	200,029		$	414,557		$	387,178
Natural gas sales		17,200			34,531			45,418			90,047
Royalty revenues		379			3,000			1,277			3,941
Sale of oil and natural gas properties		-			-			-			27,120
Total revenues		278,153			237,560			461,252			508,286
Operating Expenses:
Oil and gas producing activities:
Lease operating expenses		204,897			198,069			487,455			414,868
Production taxes		21,953			19,374			36,067			37,799
Depreciation, depletion, amortization and accretion		120,268			133,988			298,810			341,957
Impairment		-			-			252,000			-
Gas gathering:
Operating expenses		-			-			-			1,406
Depreciation		-			11,055			-			22,110
General and administrative expenses:
Director fees		10,000			12,000			20,000			22,000
Investor relations		5,406			7,465			7,313			10,628
Legal, auditing and professional fees		56,713			61,290			85,884			73,855
Consulting fees executive services-Related Parties		24,232			36,000			40,732			83,400
Other administrative expenses		8,006			25,285			23,172			44,439
Depreciation		-			143			-			285
Total operating expenses		451,475			504,669			1,251,433			1,052,747
Operating loss		(173,322	)		(267,109	)		(790,181	)		(544,461	)
Other income (expense)
Interest income (expense), net		(22,237	)		(31,522	)		(44,952	)		(58,680	)
Total other expense		(22,237	)		(31,522	)		(44,952	)		(58,680	)
Loss before income taxes		(195,559	)		(298,631	)		(835,133	)		(603,141	)
Income tax benefit (expense)		-			-			-			-
Net loss	$	(195,559	)	$	(298,631	)	$	(835,133	)	$	(603,141	)
Net Loss Applicable to Common Stockholders:
Net loss	$	(195,559	)	$	(298,631	)	$	(835,133	)	$	(603,141	)
Preferred stock dividends declared		(47,470	)		-			(95,979	)		-
Net loss applicable to common stockholders	$	(243,029	)	$	(298,631	)	$	(931,112	)	$	(603,141	)
Loss Per Share Applicable to Common Stockholders:
Basic	$	(0.02	)	$	(0.02	)	$	(0.06	)	$	(0.05	)
Diluted	$	(0.02	)	$	(0.02	)	$	(0.06	)	$	(0.05	)
Weighted Average Number of Common Shares Outstanding:
Basic		14,469,700			12,753,000			14,382,550			12,732,000
Diluted		14,469,700			12,753,000			14,382,550			12,732,000
The Accompanying Notes are an Integral Part of These Financial Statements.

The Accompanying Notes are an Integral Part of These Financial Statements.

ARÊTE INDUSTRIES, INC.

UNAUDITED CONDENSED STATEMENTS OF STOCKHOLDERS' EQUITY

	Class A Preferred Stock				Common Stock				Accumulated
	Shares		Amount		Shares		Amount		Deficit			Total
Balances, January 1, 2014		-	$	-		12,558,459	$	21,294,887	$	(16,118,542	)	$	5,176,345
Balances, January 1, 2016		267	$	2,670,000		14,295,413	$	21,502,635	$	(20,865,595	)	$	3,307,040
Common Stock Issued for Services - Related Parties		-		-		206,666		32,516		-			32,516
Common Stock Issued for Directors Fees		-		-		530,288		75,232		-			75,232
Issuance of common stock for oil and gas acquisition		-		-		1,000,000		100,000		-			100,000
Issuance of series A2 preferred stock		177		1,770,000		-		-		-			1,770,000
Preferred stock issued for settlement of debt with a related party		90		900,000		-		-		-			900,000
Net loss		-		-		-		-		(4,747,053	)		(4,747,053	)
Balances, December 31, 2015		267	$	2,670,000		14,295,413	$	21,502,635	$	(20,865,595	)	$	3,307,040
Issuance of common stock for services		-		-		316,667		25,334		-			25,334
Issuance of common stock related to notes payable (See Note 7)		-		-		3062,~~000~~500		37,~~600~~500		-			37,~~600~~500
Issuance of series A2 preferred stock		5		50,000		-		-		-			50,000
Preferred stock dividends		-		-		-		-		(95143,~~979~~970	)		(95143,~~979~~970	)
Net loss		-		-		-		-		(~~835~~1,~~133~~115,454	)		(~~835~~1,~~133~~115,454	)
Balances, June 30, 2016		272	$	2,720,000		14,642,080	$	21,531,569	$	(21,796,707	)	$	2,454,862
Balances, September 30, 2016		272	$	2,720,000		14,674,580	$	21,535,469	$	(22,125,019	)	$	2,130,450

The Accompanying Notes are an Integral Part of These Financial Statements.

ARÊTE INDUSTRIES, INC.
CONDENSED STATEMENTS OF CASH FLOWS (Unaudited)
	For the six months ended June 30,
	For the nine months ended September 30,
	2016			2015
Cash Flows from Operating Activities:
Net loss	$	(~~835~~1,~~133~~115,454	)	$	(~~603~~992,~~141~~837	)
Adjustments to reconcile net loss to net cash provided by
(used in) operating activities:
Depreciation, depletion and amortization		~~251~~328,000			~~329~~509,~~717~~698
Accretion of discount on asset retirement obligations		4775,~~810~~333			3455,~~635~~187
Gain on sale of oil and gas properties		-			(27,120	)
Common stock issued in exchange for services		25,334			2855,~~500~~165
Impairment expense		252,000			-
Changes in operating assets and liabilities:
Accounts receivable		(1816,~~421~~042	)		8679,~~601~~443
Prepaid expenses and other		720,~~209~~722			1325,~~467~~715
Accounts payable		66(2,~~091~~078	)		29118,~~496~~044
Accounts payable - related parties and director's fees		31,398			-
Amortization of loan servicing fees		938			-
Accounts payable - DNR Oil & Gas, Inc.		(234,022	)		-
Settlement of Asset Retirement Obligation		(4,530	)		-
Other accrued expenses and accrued interest		371,~~230~~551			78115,~~754~~133
Net cash used in operating activities		(~~369~~434,~~504~~226	)		(2961,~~091~~572	)
Cash Flows from Investing Activities:
Capital expenditures for property and equipment		(373	)		(9364,~~116~~416	)
Proceeds from sale of oil & gas properties		-			50,000
Net cash used in investing activities		(373	)		(4314,~~116~~416	)
Cash Flows from Financing Activities:
Proceeds from notes payable		~~125~~250,500			6067,000
Principal payments on notes payable		(~~118~~137,~~002~~248	)		(1219,~~270~~658	)
Proceeds received from subscription receivable		105,000			-
Preferred stock dividends paid		(4895,~~509~~979	)		-
Proceeds received from issuance of Series A2 Preferred Stock		50,000			-
Net cash provided by financing activities		~~113~~172,~~989~~273			47,~~730~~342
Net decrease in cash and equivalents		(~~255~~262,~~888~~326	)		(2428,~~477~~646	)
Cash and equivalents, beginning of period		521,666			30,755
Cash and equivalents, end of period	$	~~265~~259,~~778~~340		$	62,~~278~~109
Supplemental Disclosure of Cash Flow Information:
Cash paid for interest	$	40,881		$	34,838
Additions to oil & gas properties financed through accounts payable	$	-		$	3,465
Accrued dividends	$	47,470		$	-
Cash paid for interest	$	62,052		$	55,913
Common stock issued for loan closing costs	$	3,600		$	-
Accrued dividends	$	47,991		$	-
The Accompanying Notes are an Integral Part of These Financial Statements.
Common stock issued as a prepayment for services	$	-		$	13,333
Common stock issued for director fees payable	$	-		$	20,900
Common stock issued for loan closing costs	$	7,500		$	-

The Accompanying Notes are an Integral Part of These Financial Statements.

Note 1 - Organization and Nature of Operations

Arête Industries, Inc. ("Arête" or the "Company"), is a Colorado corporation that was incorporated on July 21, 1987. The Company seeks to focus on acquiring interests in traditional oil and gas ventures, and seek properties that offer profit potential from overlooked and by-passed reserves of oil and natural gas, which may include shut-in wells, in-field development, stripper wells, re-completion and re-working projects. In addition, the Company's strategy includes purchase and sale of acreage prospective for oil and natural gas and seeking to obtain cash flow from the sale and farm out of such prospects.

Note 2 - Summary of Significant Accounting Policies

Basis of presentation

These statements have been prepared in accordance with the rules and regulations of the Securities and Exchange Commission ("SEC") and accounting principles generally accepted in the United States ("GAAP") for interim financial information. They do not include all information and notes required by GAAP for complete financial statements. However, except as disclosed herein, there has been no material change in the information disclosed in the notes to financial statements included in Arête's Annual Report on Form 10-K for the year ended December 31, 2015 as filed with the SEC. In the opinion of management, the accompanying unaudited financial statements contain all adjustments, consisting of normal recurring accruals necessary for a fair presentation of the financial position as of ~~June~~September 30, 2016, and December 31, 2015, and the results of operations, changes in stockholders' equity, and cash flows for the quarters ended ~~June,~~September 30, 2016, and 2015. Operating results for the interim periods presented are not necessarily indicative of the results that may be expected for a full year. The Company's 2015 Annual Report on Form 10-K includes certain definitions and a summary of significant accounting policies and should be read in conjunction with this Form 10-Q.

In connection with the preparation of its unaudited condensed financial statements, the Company evaluated events subsequent to the balance sheet date of ~~June~~September 30, 2016, through the filing date of this report.

Liquidity and Management's Plans

The Company ~~has~~ incurred significant net operating losses during the ~~six~~nine months ended ~~June~~September 30, 2016, and for the fiscal year ended December 31, 2015. The Company also has negative working capital at ~~June~~September 30, 2016, and is currently in default with ~~one~~oneof of its creditors for which it has a note payable. This history of operating losses, negative working capital and note defaults, along with low commodity prices, ~~may~~will likely adversely affect the Company's ability to access the capital it needs to continue operations on terms acceptable to the Company ~~when such capital is needed~~. However, due to the Company's limited capital raise (see Note 6 - Stock transactions and preferred stock dividends), its entry into extensions of some of its notes payable to long-term debt (see Note 7 - Notes and advances payable) and the acquisition of additional producing wells and properties at the end of 2015, the Company believes that it can raise additional capital to fund its current operations over, at least 12 months from the date of this filing. The Company's ability to continue as a going concern is dependent upon its ability to secure other sources of financing and attain profitable operations, which it has not achieved for several quarters. The Company continues to pursue additional sources of financing but there can be no assurance that such financing will be completed on terms favorable to the Company, if at all.

Use of estimates

Preparation of the Company's financial statements in accordance with GAAP requires management to make various assumptions, judgments and estimates that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Changes in these assumptions, judgments and estimates will occur as a result of the passage of time and the occurrence of future events and, accordingly, actual results could differ from amounts initially established.

The most significant areas requiring the use of assumptions, judgments and estimates relate to the volumes of natural gas and oil reserves used in calculating depreciation, depletion and amortization ("DD&A"), the amount of expected future cash flows used in determining possible impairments of oil and gas properties and the amount of future capital costs used in these calculations. Assumptions, judgments and estimates also are required in determining future asset retirement obligations and impairments of undeveloped properties.

Oil and Gas producing activities

The Company's oil and gas exploration and production activities are accounted for using the successful efforts method. Under this method, all property acquisition costs and costs of exploratory and development wells are capitalized when incurred, pending determination of whether the well has proved reserves. If an exploratory well does not result in proved reserves, the costs of drilling the well are charged to expense and included within cash flows from investing activities in the Statements of Cash Flows. The costs of development wells are capitalized whether productive or nonproductive. Oil and gas lease acquisition costs are also capitalized.

Other exploration costs, including certain geological and geophysical expenses and delay rentals for oil and gas leases, are charged to expense as incurred. The sale of a partial interest in a proved property is accounted for as a cost recovery and no gain or loss is recognized as long as this treatment does not significantly affect the unit-of-production DD&A rate. A gain or loss is recognized for all other sales of proved properties and is classified in other operating revenues. Maintenance and repairs are charged to expense, and renewals and betterments are capitalized to the appropriate property and equipment accounts.

The Company estimates the expected undiscounted future cash flows of its oil and gas properties and compares such undiscounted future cash flows to the carrying amount of the oil and gas properties to determine if the carrying amount is recoverable. If the carrying amount exceeds the estimated undiscounted future cash flows, the Company will adjust the carrying amount of the oil and gas properties to fair value. The factors used to determine fair value include, but are not limited to, recent sales prices of comparable properties, the present value of estimated future cash flows, net of estimated operating and development costs using estimates of reserves, future commodity pricing, future production estimates, anticipated capital expenditures and various discount rates commensurate with the risk and current market conditions associated with realizing the expected cash flows projected. Once incurred, a write-down may not be reversed in a later period. For the six month periods ended June 30, 2016 and 2015, the Company recorded impairment expense of $252,000 and $0, respectively, against its oil and gas properties.8

The Company estimates the expected undiscounted future cash flows of its oil and gas properties and compares such undiscounted future cash flows to the carrying amount of the oil and gas properties to determine if the carrying amount is recoverable. If the carrying amount exceeds the estimated undiscounted future cash flows, the Company will adjust the carrying amount of the oil and gas properties to fair value. The factors used to determine fair value include, but are not limited to, recent sales prices of comparable properties, the present value of estimated future cash flows, net of estimated operating and development costs using estimates of reserves, future commodity pricing, future production estimates, anticipated capital expenditures and various discount rates commensurate with the risk and current market conditions associated with realizing the expected cash flows projected. Once incurred, a write-down may not be reversed in a later period. For the nine month periods ended September 30, 2016 and 2015, the Company recorded impairment expense of $252,000 and $0, respectively, against its oil and gas properties.

The provision for DD&A of oil and gas properties is calculated based on proved reserves on a field-by-field basis using the unit-of-production method. Natural gas is converted to barrel equivalents, BOE, at the rate of six Mcf of natural gas to one barrel of oil. Estimated future dismantlement, restoration and abandonment costs, which are net of estimated salvage values, are taken into consideration.

Unproved oil and gas properties are periodically assessed for impairment on a project-by-project basis. These impairment assessments are affected by the results of exploration activities, commodity price outlooks, planned future sales or expirations of all or a portion of such projects. If the estimated future net cash flows attributable to such projects are not expected to be sufficient to fully recover the costs invested in each project, the Company will recognize an impairment loss at that time. There was no provision for impairment recorded against its unproved property for the ~~six~~nine month periods ended ~~June~~September 30, 2016 and 2015.

Revenue recognition

The Company records revenues from the sale of crude oil, natural gas and natural gas liquids ("NGL") when delivery to the purchaser has occurred and title has transferred. The Company uses the sales method to account for gas imbalances. Under this method, revenue is recorded on the basis of gas actually sold by the Company. In addition, the Company will record revenue for its share of gas sold by other owners that cannot be volumetrically balanced in the future due to insufficient remaining reserves. The Company also reduces revenue for other owners' gas sold by the Company that cannot be volumetrically balanced in the future due to insufficient remaining reserves. The Company's remaining over and under produced gas balancing positions are considered in the Company's proved oil and gas reserves. Gas imbalances at ~~June~~September 30, 2016 and December 31, 2015 were not material.

Earnings per share

Basic net income (loss) per share of common stock is calculated by dividing net income (loss) attributable to common stockholders by the weighted average number of common shares outstanding during each period. Diluted net income (loss) attributable to common stockholders is calculated by dividing net income (loss) attributable to common stockholders by the weighted average number of common shares outstanding and other dilutive securities. The only potentially dilutive securities for the diluted earnings per share calculations consist of Series A2 preferred stock that is convertible into common stock at an exchange price of $2.00 per common share. As of ~~June~~September 30, 2016, the convertible preferred stock had an aggregate liquidation preference of $2,~~720~~767,~~000~~991 and was convertible to 1,~~360~~384,000 shares of common stock. These shares were excluded from the earnings per share calculation because they would be anti-dilutive.

The following table sets forth the calculation of basic and diluted earnings per share:

	Three month periods ended June 30,						Six month periods ended June 30,
	Three month periods ended September 30,						Nine month periods ended September 30,
	2016			2015			2016			2015
Net loss available to common shareholders – Basic	$	(~~243~~328,~~029~~312	)	$	(~~298~~389,~~631~~696	)	$	(~~931~~1,~~112~~259,424	)	$	(~~603~~992,~~141~~837	)
Plus: Preferred stock dividends		-			-			-			-
Net loss available to common shareholders – Diluted	$	(~~243~~328,~~029~~312	)	$	(~~298~~389,~~631~~696	)	$	(~~931~~1,~~112~~259,424	)	$	(~~603~~992,~~141~~837	)
Weighted average common shares outstanding – Basic		14,~~469~~673,700			12,~~753~~966,000			14,~~382~~450,550			12,~~732~~764,000
Add: Dilutive effect of stock options		-			-			-			-
Add: Dilutive effect of preferred stock		-			-			-			-
Weighted average common shares outstanding – Diluted		14,~~469~~673,700			12,~~753~~966,000			14,~~382~~450,550			12,~~732~~764,000
Net loss per common share:
Basic	$	(0.02	)	$	(0.0203	)	$	(0.0609	)	$	(0.0508	)
Diluted	$	(0.02	)	$	(0.0203	)	$	(0.0609	)	$	(0.0508	)

New accounting pronouncements

In January 2016, the FASB issued ASU 2016-01, "Recognition and Measurement of Financial Assets and Financial Liabilities." ASU 2016-01 changes certain guidance related to the recognition, measurement, presentation and disclosure of financial instruments. This update is effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. Early adoption is not permitted for the majority of the update, but is permitted for two of its provisions. The Company is evaluating the new guidance and has not determined the impact this standard may have on its financial statements.

In February 2016, FASB issued ASU 2016-02, "Leases." ASU 2016-02 requires the recognition of lease assets and lease liabilities by lessees for those leases currently classified as operating leases and makes certain changes to the way lease expenses are accounted for. This update is effective for fiscal years beginning after December 15, 2018 and for interim periods beginning the following year. This update should be applied using a modified retrospective approach, and early adoption is permitted. The Company is evaluating the new guidance and has not determined the impact this standard may have on its financial statements.

In January 2017, FASB issued ASU 2017-01, "Business Combinations." These amendments clarify the definition of a business. The amendments affect all reporting organizations that must determine whether they have acquired or sold a business. The definition of a business affects many areas of accounting including acquisitions, disposals, goodwill, and consolidation. The amendments are intended to help companies and other organizations evaluate whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. The Company is evaluating the new guidance and has not determined the impact this standard may have on its financial statements.

Note 3 - Oil and Gas Properties

The following table sets forth information concerning the Company's oil and gas properties:

	June 30, 2016			December 31, 2015
	September 30, 2016			December 31, 2015
Proved oil and gas properties at cost, net of impairment	$	8,431,505		$	8,683,273
Unproved oil and gas properties at cost, net of impairment		154,977			154,836
Accumulated depreciation, depletion and amortization		(3,~~474~~551,000	)		(3,223,000	)
Oil and gas properties, net	$	5,~~112~~035,482		$	5,615,109

During the ~~six~~nine month periods ended ~~June~~September 30, 2016 and 2015, the Company recorded depletion expense of $~~251~~328,000 and $~~307~~476,~~322~~105 respectively. The Company recorded impairment expense of $252,000 and $0 for the ~~six~~nine month periods ended ~~June~~September 30, 2016 and 2015, respectively.

Acquisitions

In 2011, the Company entered into a purchase and sale agreement ("DNR and Tindall PSA") and other related agreements and documents with Tucker Family Investments, LLLP, which is referred to as "Tucker"; DNR Oil & Gas, Inc. which is referred to as "DNR"; and Tindall Operating Company, which is referred to as "Tindall", and collectively are referred to as the "Sellers", for the purchase of certain oil and gas operating properties in Colorado, Kansas, Wyoming, and Montana. DNR is owned primarily by an officer and director of the Company, Charles B. Davis, and he is an affiliate of Tucker and Tindall. The consideration for the purchase was determined by bargaining between management of the Company and Mr. Davis, and the Company used reports of independent engineering firms to analyze the purchase price. The base purchase price was paid in full on September 29, 2011.

On January 19, 2016, but effective December 31, 2015, (the "Effective Date") the Company entered into a Settlement Agreement with Tucker, DNR and Tindall regarding the DNR and Tindall PSA and other related matters. In consideration of the amounts indicated below, the parties (i) terminated Exhibits C and C-2 to the DNR and Tindall PSA for all purposes; (ii) extinguished all liabilities of the Company under Exhibit C of the DNR and Tindall PSA including $250,000 related to the increase in oil prices after the acquisition; (iii) agreed that the promissory note of $792,151 due to DNR (See Note 7 – Notes and Advances Payable) and accrued interest thereon was paid in full; and (iv) released each other against any and all claims which have been raised or could have been raised among them. Specifically, Exhibits C and C-2 to the DNR and Tindall PSA related to potential payments that would have needed to have been made by the Company in the event oil prices increased to certain levels and related to certain payments to have been made by the Company in the event it sold certain properties purchased under the DNR and Tindall PSA. Exhibits C and C-2 were terminated and extinguished (including any amounts owed thereunder including an alleged amount of $250,000 under Exhibit C to the DNR and Tindall PSA) in exchange for 25 fully paid nonassessable restricted shares of our 7% Series A2 Convertible Preferred Stock. Consideration to pay the above promissory note in full consisted of the issuance to DNR of 65 fully paid, nonassessable restricted shares of its 7% Series A2 Convertible Preferred Stock, and paying DNR $303,329 in cash, which was paid January 19, 2016. A description of the terms of the 7% Series A2 Convertible Preferred Stock, including its terms of conversion into shares of the Company's common stock is set forth below in Note 6 - Stock transactions and preferred stock dividends. The Company recorded an expense of $141,099 included in other operating expense in the statement of operations at December 31, 2015, as a result of this transaction. At ~~June~~September 30, 2016, the Company's only remaining liabilities to DNR related to oil and gas operations are recorded in Accounts payable – DNR Oil & Gas, Inc. on the balance sheet.

On December 30, 2015, the Company completed an asset acquisition pursuant to a purchase and sale agreement executed on November 25, 2015, but effective December 1, 2015 (the "Wellstar Purchase and Sale Agreement ") with Wellstar Corporation (the "Seller"), an unaffiliated corporation. The assets acquired were producing oil and gas leases in Sumner County, Kansas and Kimball County, Nebraska (collectively, the "Properties" and individually, the "Padgett Properties" and the "Nebraska Properties"). The Company acquired 51% of Seller's interest (ranging from 47% to 100% of the working interests) in the Padgett Properties and acquired 100% of the Seller's interest (100% of the working interests) in the Nebraska Properties for aggregate consideration of $1,100,000 and the issuance of 1,000,000 shares of the Company's restricted common stock valued at $0.10 per share at the date of closing, or $100,000.

Note 4 – Fair Value Measurements

FASB ASC 820, "Fair Value Measurements and Disclosures", establishes a framework for measuring fair value. That framework provides a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets and liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). The three levels of the fair value hierarchy under FASB ASC 820 are described as follows:

Level 1 – Observable inputs, such as unadjusted quoted prices in active markets, for substantially identical assets and liabilities.

Level 2 – Observable inputs other than quoted prices within Level 1 for similar assets and liabilities. These include quoted prices for similar assets and liabilities in active markets, quoted prices for identical assets and liabilities in markets that are not active, or other inputs that are observable or can be corroborated by observable market data. If the asset or liability has a specified or contractual term, the input must be observable for substantially the full term of the asset or liability.

Level 3 – Unobservable inputs that are supported by little or no market activity, generally requiring a significant amount of judgment by management. The assets or liabilities fair value measurement level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. Valuation techniques used need to maximize the use of observable inputs and minimize the use of unobservable inputs.

The methods described above may produce a fair value calculation that may not be indicative of net realizable value or reflective of future fair values. Further, although the Company believes its valuation methods are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date.

Upon completion of wells, the Company records an asset retirement obligation at fair value using Level 3 assumptions and this is a non-recurring estimate.

~~Nonfinancial~~Impairment ~~assets~~of ~~and~~long-lived ~~liabilities~~assets are ~~measured~~determined ~~at fair value~~ on a ~~nonrecurring~~non-recurring basis ~~upon~~using ~~impairment.~~Level ~~The~~3 carrying amounts of other financial instruments including cash and cash equivalents, accounts receivable, account payables, accrued liabilities and long term debt in our balance sheet approximates fair value as of June 30, 2016 and December 31, 2015.assumptions

Nonfinancial assets and liabilities are measured at fair value on a nonrecurring basis upon impairment. The carrying amounts of other financial instruments including cash and cash equivalents, accounts receivable, account payables, accrued liabilities and long term debt in our balance sheet approximates fair value as of September 30, 2016 and December 31, 2015.

Note 5 - Income taxes

The book to tax temporary differences resulting in deferred tax assets and liabilities are primarily net operating loss carry forwards of approximately $8.3 million which expire in 2018 through 2035. A 100% valuation allowance has been established against the deferred tax assets, as utilization of the loss carry forwards and realization of other deferred tax assets cannot be reasonably assured. For the period ended ~~June~~September 30, 2016, the Company did not recognize any income tax benefit due to the valuation allowance.

The Company recognizes the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained upon examination by the taxing authorities, based upon the technical merits of the position. As of ~~June~~September 30, 2016, the Company had no unrecognized tax benefits.

Note 6 - Stock transactions and preferred stock dividends

Common stock

On May 11, 2016, the Company issued 316,667 shares of restricted common stock to its Chief Financial Officer as compensation for services performed from January 1 through May 31, 2016.

On June 29, 2016, the Company issued 30,000 shares of restricted common stock as a loan closing cost related to one of its notes payable valued at $3,600 (see Note 7 – Notes and advances payable).

On July 1, 2016, the Company issued 20,000 shares of restricted common stock as a loan closing cost related to one of its notes payable valued at $2,400 (see Note 7 – Notes and advances payable).

On July 5, 2016, the Company issued 12,500 shares of restricted common stock as a loan closing cost related to one of its notes payable valued at $1,500 (see Note 7 – Notes and advances payable).

Preferred stock

On December 11, 2015, the Company began a private placement of its Series A2 7% Preferred Convertible Stock with a maximum amount of 600 shares at $10,000 per share or $6,000,000. At ~~June~~September 30, 2016, the Company had $2,720,000 (272 shares) outstanding. 177 shares ($1,770,000) were sold for cash during the fiscal year ended December 31, 2015, 90 shares ($900,000) were issued to DNR as part of the consideration for a settlement entered into with DNR during fiscal year ended December 31, 2015 and 5 shares ($50,000) were sold on January 7, 2016.

Note 7 - Notes and advances payable

Notes payable consist of the following as of the date indicated:

	June 30, 2016		December 31, 2015
	September 30, 2016		December 31, 2015
Officers, directors and affiliates:
Note payable, interest 7.0%, due January 2019 (1)		3733,~~243~~924		43,803
Collateralized note payable (2)		120,728		120,728
Total officers, directors and affiliates		~~157~~154,~~971~~652		164,531
Less: Current portion of officers, directors, and affiliates		134,~~354~~595		13,152
Long-term portion of officers, directors, and affiliates	$	2320,~~617~~057	$	151,379
Unrelated parties:
Notes payable, interest at 7.5%, due April 2016 (3)	$	100,000	$	100,000
Notes payable, interest at 7.5%, due January 2019 (3)	$	100,000	$	100,000
Note payable, due March 2017 (4)		165,953		169,660
Note payable, due March 2018 (4)		150,000		150,000
Note payable, interest variable (see below) due June 28, 2018 (5)		523,000		616,105
Note payable, due December 2018 (5)		15,014		19,660
Note payable, interest at 7.0%, due August 2016 (6)		62,000		62,000
Note payable, interest variable (see below) due June 2018 (6)		523,000		616,105
Notes payable, interest at 7.0%, due January 2017 (7)		27,718		32,606
Note payable, interest at 7.0%, due August 2016 (7)		62,000		62,000
Notes payable, interest at 7.0%, due January 2016, Extended to May 2016 (8)		183,000		183,000
Notes payable, interest at 7.0%, due January 2019 (8)		25,253		32,607
Notes payable, interest at 4.957%, due October 2017 (9)		15,759		-
Notes payable, interest at 7.0%, due June 2018 (9)		183,000		183,000
Notes payable, net of discount, interest at 7.0%, due June 29, 2018 (10)		96,400		-
Notes payable, interest at 4.957%, due October 2017 (10)		3,236		-
Total unrelated parties		1,173,830		1,163,371
Notes payable, net of discount, interest at 7.0%, due June 2018 (11)		96,850		-
Less: Current portion of unrelated parties		253,854		989,853
Notes payable, net of discount, interest at 7.0%, due June 2018 (12)		97,900		-
Long-term portion of unrelated parties	$	919,976	$	173,519
Notes payable, net of discount, interest at 7.0%, due June 2018 (13)		23,688		-
Total unrelated parties		1,279,941		1,163,372
Less: Current portion of unrelated parties		81,502		989,853
Long-term portion of unrelated parties	$	1,198,439	$	173,519

(1)

In January 2014, we memorialized certain short-term liabilities with owed to one of our directors, Charlie Davis, into a formal promissory note. This note accrues interest at an annual rate of 7.0% with monthly payments equal to $1,316 (principal and interest) and will mature on January 1, 2019.

(2) On April 29, 2013, the Company executed a promissory note under which the Company agreed to pay Apex Financial Services Corp, a Colorado corporation, ("Apex") the principal sum of $120,728, with interest accruing at an annual rate of 7.5%, with principal and interest due on March 31, 2017. The Company also agreed to assign 75% of its operating income from its oil and gas operations and any lease or well sale or any other asset sales to Apex to secure the debt. Apex is 100% owned by the CEO, director, and shareholder of the Company, Nicholas L. Scheidt. The Company paid a loan fee to Apex of $10,000. In the event of default on the note and failure to cure the default in ten days, Apex may accelerate payment and the annual interest rate on the note will accrue at 18%. Default includes failure to pay the note when due or if the Company borrows any other monies or offers security in the Company or in the collateral securing the note prior to the note being paid in full. The Company obtained a default waiver from Apex related to the new notes entered into through the ~~six~~nine month period ended ~~June~~September 30, 2016. The Company has not had operating income or had any lease or well sales in the current fiscal year; therefore, no payments have been made to Apex through ~~June~~September 30, 2016.

(3)

On March 28, 2012, the Company executed a promissory note with Pikerni, LLC ("Pikerni"). This note was extended and amended on April 1, 2015,extending the maturity date of the note to April 1, 2016, with principal payments of $5,000 due on June 30, 2015, September 30, 2015, December 31, 2015, and March 31, 2016, and the remaining principal balance of $80,000 due on April 1, 2016. The note accrues interest at an annual rate of 7.5% and is payable quarterly. The Company did not make any of the principal payments and was in default on this note, however, in January 2016 the Company entered into an extension agreement with Pikerni, with an effective date of June 15, 2016. The principal amount of $100,000 was extended to March 30, 2018, with interest continuing to accrue at an annual rate of 7.5% and interest payments continuing to be paid in 90-day intervals.

(4) On March 28, 2012, the Company executed a Promissory Note with Fairfield Management Group, LLC, subsequently assigned to Donald Prosser (former CFO and Director) ("Prosser") during the fiscal year ended December 31, 2015. The note has a principal balance of $150,000, accrues interest at 7.5% payable monthly and has a maturity date of March 31, 2016, which was subsequently extended to March 31, 2017.12

(4) On ~~December~~March 3128, ~~2013~~2012, the Company executed a ~~promissory~~Promissory ~~note~~Note with ~~Mr.~~Fairfield Management Group, LLC, subsequently assigned to Donald Prosser ~~for~~(former ~~$28~~CFO and Director) ("Prosser") during the fiscal year ended December 31,~~500~~ 2015. ~~This~~The note has a principal balance of $150,000, accrues interest at 7.5% payable monthly and had a ~~rate~~maturity date of ~~7.0%~~March ~~with~~31, ~~monthly~~2016, ~~payments~~which ~~equal~~was subsequently extended to ~~$564~~March ~~(principal~~31, 2017 and ~~interest)~~extended again on May 3, 2017 to March 30, 2018. The Company did not make the principal payment of $150,000 on March 31, 2017, and ~~matures~~was in default on ~~January~~this 1note payable before the May 3, ~~2019~~2017 extension agreement.

13(5) On December 31, 2013, the Company executed a promissory note with Mr. Prosser for $28,500. This note accrues interest at a rate of 7.0% with monthly payments equal to $564 (principal and interest) and matures on January 1, 2019.

(56) On January 28, 2014, we entered into a line of credit loan agreement for $1,500,000 due January 15, 2015, subsequently extended to June 28, 2018. The terms of the note are as follows: 1) the accrued interest is payable monthly starting February 28, 2014, 2) the interest rate is variable based on an index calculated based on a prime rate as published by the Wall Street Journal index plus an add on index with the current and minimum rate of 6.5%, the note has draw provisions and is collateralized by the wells and leases owned by the Company, a certificate of deposit for $500,000 at CityWide Banks pledged by a related party, and 5) the personal guarantee of Nicholas Scheidt, Chief Executive Officer. The amount eligible for borrowing on the Credit Facility is limited to the lesser of (i) 65% of the Company's PV10 value of its carbon reserves based upon the most current engineering reserve report or (ii) 48 month cumulative cash flow based upon the most current engineering reserve report. In addition to the borrowing base limitation, the Company is required to maintain and meet certain affirmative and negative covenants and conditions in order to draw advances on the Credit Facility. At ~~June~~September 30, 2016, the borrowing base was $523,000. The Credit Facility contains certain representations, warranties, and affirmative and negative covenants applicable to the Company, which are customarily applicable to senior secured loan facilities. Key covenants include limitations on indebtedness, restricted payments, creation of liens on oil and gas properties, hedging transactions, mergers and consolidations, sales of assets, use of loan proceeds, change in business, and change in control. At ~~June~~September 30, 2016, the Company was in compliance with all of the covenants. The above-referenced promissory note contains customary default and acceleration provisions and provides for a default interest rate of 21% per annum. In addition, the Credit Facility contains customary events of default, including: (a) failure to pay any obligations when due; (b) failure to comply with certain restrictive covenants; (c) false or misleading representations or warranties; (d) defaults of other indebtedness; (e) specified events of bankruptcy, insolvency or similar proceedings; (f) one or more final, non-appealable judgments in excess of $50,000 that is not covered by insurance; (g) change in control (25% threshold); (h) negative events affecting the Guarantor; and (i) lender in good faith believes itself insecure. In an event of default arising from the specified events, the Credit Facility provides that the commitments thereunder will terminate and the Lender may take such other actions as permitted including, declaring any principal and accrued interest owed on the line of credit to become immediately due and payable. The Credit Facility is secured by a security interest in substantially all of the assets of the Company, pursuant to a Security Agreement, Deed of Trust and Assignment of As-Extracted Collateral entered into between the Company and Citywide Banks.

(67) On August 15, 2014, the Company redeemed the remaining 10 shares of Series A-1 Convertible Preferred Stock outstanding for consideration of $77,500, of which $15,500 was paid in cash and the remaining amount as a promissory note for $62,000. The note accrues interest at 7% per annum, payable in two installments as follows;

A payment of $31,000, plus accrued and unpaid interest was payable on August 15, 2015

A payment of $31,000, plus accrued and unpaid interest was payable on August 15, 2016

The Company did not make the August 15, 2015, or August 15, 2016, principal payment and is currently in default on this note. The Company is negotiating new terms with the note holder.

(78) On December 31, 2013, the Company executed a promissory note with Pikerni for $49,500. This note accrues interest at a rate of 7.0% per annum with monthly payments equal to $980 (principal and interest) and matures on January 1, 2019.

(89) In June 2013, in connection with the conversions of Series A-1 Preferred Stock by Burlingame Equity Investors II, LP and Burlingame Equity Investors Master Fund, LP, the Company issued unsecured promissory notes in the original principal amounts of $48,000 and $552,000, respectively, with interest at 7% per annum payable quarterly and all unpaid interest and principal due on July 23, 2014. We have agreed in writing with the holders of these two existing notes to extend the maturity date of the notes to June 18, 2018.

(9) On March 1, 2016, the Company entered into a Commercial Premium Finance Agreement – Promissory Note in the amount of $25,976 to finance one of its insurance policies. This note accrues interest at a rate of 4.957% and matured on October 17, 2016 with monthly payments equal to $3,247 (principal and interest). This note was paid in full on October 17, 2016.13

14(10) On March 1, 2016, the Company entered into a Commercial Premium Finance Agreement – Promissory Note in the amount of $25,976 to finance one of its insurance policies. This note accrues interest at a rate of 4.957% and matured on October 17, 2016. This note was paid in full on October 17, 2016.

(1011) On June 29, 2016, the Company entered into a promissory note with an unrelated party and received $100,000 and issued 30,000 shares of the Company's restricted common stock, valued at $3,600, as a loan servicing fee. This note accrues interest at the rate of 7.0% per annum with interest paid quarterly in arrears and all principal and interest due on June 29, 2018. In the event of a default, the loan will become due immediately and a default interest rate of 18.0% per year will be assessed on all amounts outstanding until paid in full. An event of default only occurs if any payment required by this note is not paid. All payments have been made on this note through the filing of this report. The loan servicing fee will be amortized over the life of the loan.

(12) On June 30, 2016, the Company entered into a promissory note with an unrelated party for $100,000 and the issuance of 20,000 shares of the Company's restricted common stock, valued at $2,400, as a loan servicing fee. This note accrues interest at the rate of 7.0% per annum with interest paid quarterly in arrears and all principal and interest due on June 30, 2018. In the event of a default, the loan will become due immediately and a default interest rate of 18.0% per year will be assessed on all amounts outstanding until paid in full. An event of default only occurs if any payment required by this note is not paid. The proceeds for this note were received on July 1, 2016, upon formal closing of the transaction. The loan servicing fee will be amortized over the life of the loan.

(13) On June 30, 2016, the Company entered into a promissory note with an unrelated party for $25,000 and the issuance of 12,500 shares of the Company's restricted common stock, valued at $1,500, as a loan servicing fee. This note accrues interest at the rate of 7.0% per annum with interest paid quarterly in arrears and all principal and interest due on June 29, 2018. In the event of a default, the loan will become due immediately and a default interest rate of 18.0% per year will be assessed on all amounts outstanding until paid in full. An event of default only occurs if any payment required by this note is not paid. The proceeds from this note were received on July 5, 2016, upon formal closing of the transaction. The loan servicing fee will be amortized over the life of the loan.

Note 8 -

Asset retirement obligations

A reconciliation of the Company's asset retirement obligations ("ARO") at ~~June~~September 30, 2016, is as follows:

Balance, December 31, 2015	$	995,197
Accretion expense		47,810
Liabilities settled		(4,530	)
Balance, June 30, 2016		1,043,007
Accretion expense		75,333
Less current asset retirement obligations		(419,094	)
Balance, September 30, 2016		1,066,000
Long-term asset retirement obligations	$	623,913
Less current asset retirement obligations		(426,600	)
Long-term asset retirement obligations	$	639,400

Note 9 - ~~Subsequent events~~Litigation

On September 29, 2016, a complaint was filed against the Company and two others in the Superior Court of Arizona, Maricopa County, entitled Eric Langan, Paul McNulty, Patricia Quick, Stony Point Fund, L.P., and Jeffrey H. Wallen, D.D.S., P.C. vs. Arête Industries, Inc., Don Prosser, and Charles Davis. The complaint alleges that defendants Prosser and Davis made certain material representations to the plaintiffs in connection with the alleged purchase by the plaintiffs of $555,000 in common stock of the Company. The complaint alleges that the alleged misrepresentations were deliberate and requests damages against all of the defendants to compensate the plaintiffs for their alleged injuries resulting from the alleged misrepresentations, including punitive damages. The Company moved the case to the United States District Court for the District of Arizona, and has moved to dismiss the case, which motion has been fully briefed and itpending since December 23, 2016. The Company and the other defendants believe the action is entirely without merit and intend to vigorously defend the proceeding.

1514

Item 2 - Management's Discussion and Analysis of Financial Condition and Results of Operations

Management's Discussion and Analysis of Financial Condition and Results of Operations for the quarters ended ~~June~~September 30, 2016 and 2015 should be read together with our audited financial statements and related notes included in our Annual Report on Form 10-K for the year ended December 31, 2015, and the financial statements and footnotes included in this Quarterly Report on Form 10-Q. This Quarterly Report on Form 10-Q, including the following discussion, contains trend analysis and other forward-looking statements within the safe harbor provisions of the Private Securities Litigation Reform Act of 1995. Any statements in this Quarterly Report on Form 10-Q that are not statements of historical facts are forward-looking statements. These forward-looking statements made herein are based on our current expectations, involve a number of risks and uncertainties and should not be considered as guarantees of future performance.

General Overview

We are an independent energy company ~~engaged~~whose inbusiness ~~the~~plan ~~acquisition~~is to acquire, ~~exploration~~explore and ~~development~~develope of oil, natural gas and natural gas liquids ("NGL's") in the United States. Due to the limited capital and low commodity prices, we have not been able to execute on our business plan since 2015. Our long-term strategy is to seek to deliver net asset value per share growth to our investors via attractive investments within the oil and gas industry. WeIn the event we are able to obtain sufficient additional capital we expect to seek properties that offer profit potential from overlooked and by-passed reserves of oil and natural gas, which may include shut-in wells, in-field development, stripper wells, re-completion and re-working projects. In addition, we seek acreage, prospective for oil and natural gas, to purchase in order to obtain cash flow from the re-sale and farm out of such prospects.

We do not ~~intend to~~ operate any of the properties in which we have an interest. As a result, we have limited ability to exercise influence over, and control the risks associated with operations of these properties. The failure of an operator of our wells to adequately perform operations, an operator's breach of the applicable agreements or an operator's failure to act in ways that are in our best interests could reduce our ability to be successful in finding reserves and could create a liability for us for the operator's failure to properly operate the project and adhere to applicable safety and environmental standards.

It is our desire to provide an understanding of the Company's past performance, its financial condition and its prospects for the future. Accordingly, we discuss and provide our analysis of the following:

•

Results of operations;

•

Liquidity and capital resources;

•

Contractual obligations;

•

Off balance sheet arrangements;

•

Critical accounting policies; and

•

New accounting pronouncements.

Oil, Gas, and NGL Prices

Our financial condition and the results of our operations are significantly affected by the prices we receive for our oil, gas, and NGL production, which can fluctuate dramatically. Our oil and gas is sold under our operators' contracts paying us various industry posted prices, adjusted for basis differentials. We are paid the average of the daily settlement price for the respective posted prices for the period in which the product is sold, adjusted for quality, transportation and location differentials.

We expect future prices for oil, gas, and NGLs to continue to be volatile. In addition to supply and demand fundamentals, as a global commodity, the price of oil is affected by real or perceived geopolitical risks in all regions of the world as well as the relative strength of the dollar compared to other currencies. Oil markets continue to be unstable.

Results of Operations for the Three and ~~Six~~Nine months Ended ~~June~~September 30, 2016 and 2015

Presented below is a discussion of our results of operations for the three and ~~six~~nine months ended ~~June~~September 30, 2016 and 2015.

Net Loss Applicable to Common Stockholders

Three Months Ended ~~June~~September 30, 2016 and 2015

Net loss applicable to common stockholders for the three months ended ~~June~~September 30, 2016 and 2015 was $~~243~~328,~~029~~312 and $~~298~~389,~~631~~696, respectively., ~~The~~a decrease inof ~~the~~$61,384. ~~net~~Oil ~~loss~~and ofgas sales decreased $5513,~~602~~642, orwhich ~~18.6%~~were ~~was~~ due to alower ~~slight~~realized ~~increase~~oil inprices. ~~lease~~Lease operating expenses, ~~accretion expense and production taxes, which in aggregate~~ increased $1542,~~981~~367, ~~offset~~which bywas anmostly ~~increase~~related into ~~oil~~workover ~~and~~expenses ~~gas~~incurred ~~salesof $40,593 due~~ to ~~greater~~replace ~~volumes~~pumps ofand ~~oil~~repair ~~being~~wells ~~sold~~in ~~during~~an ~~the~~effort ~~three~~to ~~months~~enhance ~~ended~~production. ~~June~~These ~~30,~~increases ~~2016,~~were ~~and~~offset toby decreases in production taxes, DD&A expense ~~of $31,492, general~~ and ~~administrative ("~~G&A") ~~expenses of $37~~costs,~~683~~ ~~and~~which ~~interest~~decreased ~~expense, net of interest income of~~ $9162,~~285~~079. The Company ~~also~~ declared dividends on its Series 2 Class A Preferred Stock ~~equal~~of to $47,~~470~~991 during the three months ended ~~June~~September 30, 2016, compared to none in the prior year's period.

~~Six~~Nine Months Ended ~~June~~September 30, 2016 and 2015

Net loss applicable to common stockholders for the ~~six~~nine months ended ~~June~~September 30, 2016 and 2015 was $~~931~~1,~~112~~259,424 and $~~603~~992,~~141~~837, respectively. The current year net loss was greater by $~~327~~266,~~971~~587 or 5426.49%, primarily due to a noncash impairment charge of $252,000 to the carrying value of our proved oil and gas properties incurred during the three months ended March 31, 2016,. asOur ~~well as, lower~~ oil and gas sales ofwere lower by $4760,~~034~~676 compared to the same period in the prior year, which included a gain on sale of an oil and gas asset ~~in the prior period~~ of $27,120. InOil ~~addition,~~and ~~lease~~gas ~~operating~~producing ~~expenses~~costs ~~and~~decreased ~~accretion~~by ~~expense increased~~ $8424,~~356~~471, ingas ~~the~~gathering ~~current~~expenses ~~period,~~decreased ~~while production taxes~~$34,571 ~~DD&A, general~~ and ~~administrative ("~~G&A") expenses ~~and interest expense, net of interest income~~ decreased $~~151~~113,~~398~~984. The Company also declared dividends on its Series 2 Class A Preferred Stock equal to $95143,~~979~~970 during the ~~six~~nine months ended ~~June~~September 30, 2016.

The discussion below further discusses our results of operation for the three and ~~six~~nine months ended ~~June~~September 30, 2016 and 2015.

Oil and Gas Producing Activities

The results of our producing oil and gas properties are presented below for the three and ~~six~~nine months ended ~~June~~September 30, 2016 and 2015:

	Three Months Ended						~~Six~~Nine Months Ended
	June 30,						June 30,
	September 30,						September 30,
	2016			2015			2016			2015
Oil Sales	$	~~260~~219,~~574~~404		$	~~200~~230,~~029~~728		$	~~414~~633,~~557~~961		$	~~387~~617,~~178~~906
Natural Gas Sales		1720,~~200~~220			3422,~~531~~507			4565,~~418~~638			90112,~~047~~554
Royalty sales		~~379~~483			~~3,000~~514			1,~~277~~760			34,~~941~~455
Sale of oil and gas properties		-			-			-			27,120
Total Revenue		~~278~~240,~~153~~107			~~237~~253,~~560~~749			~~461~~701,~~252~~359			~~508~~762,~~286~~035
Lease Operating Expense		~~204~~313,~~897~~086			~~198~~270,~~069~~719			~~487~~800,~~455~~541			~~414~~685,~~868~~587
Production Taxes		2119,~~953~~367			1929,~~374~~101			3655,~~067~~434			3766,~~799~~900
Depreciation, depletion, amortization ("DD&A")		9677,000			~~116~~168,~~294~~782			~~251~~328,000			~~307~~476,~~322~~104
Accretion		2427,~~268~~523			1720,~~694~~553			4775,~~810~~333			3455,~~635~~188
Impairment expense		-			-			252,000			-
Total operating expenses		~~347~~436,~~118~~976			~~351~~489,~~431~~155			1,~~074~~511,~~332~~308			~~794~~1,~~624~~283,779
Net operating loss before general and administrative expense		(68196,~~965~~869	)		(~~113~~235,~~871~~406	)		(~~613~~809,~~080~~949	)		(~~286~~521,~~338~~744	)
Net barrels of oil sold		65,~~379~~579			~~3,968~~5495			1117,~~911~~490			814,~~905~~400
Net mcf of gas sold		10,~~323~~407			1412,~~812~~199			2535,~~427~~834			3447,~~872~~071
Boe		87,~~100~~314			67,~~437~~528			1623,~~149~~462			1422,~~717~~245
Average price for oil	$	4039.8533		$	~~50.~~41.99		$	3436.8025		$	4342.4891
Average price for gas	$	1.6794		$	21.3384		$	1.7983		$	2.5839
Lease operating expense per BOE	$	2542.3081		$	3035.7796		$	3034.1912		$	2830.1982
DD&A per BOE	$	1110.8553		$	1822.0742		$	1513.5498		$	2021.8840

17Three Months Ended September 30, 2016 and 2015

~~Three~~Our ~~Months~~oil ~~Ended~~and ~~June~~gas sales were primarily attributable to our properties in Kansas and Wyoming. Our oil sales for the three months ended September 30, 2016 and 2015, were $219,404 and $230,728, respectively, a decrease of $11,324 or 4.9%. While our oil sales volumes increased by 84 barrels, our realized price per barrel decreased $2.66 per barrel. The effect on our oil sales due to the increased sales volumes was an increase of $3,303, offset by the average realized per barrel oil price during the three months ended September 30, 2016, which was $39.33 compared to $41.99 in the same period in the prior year. This decrease in price negatively impacted our oil sales by $14,627. The increase in our oil sales production was due to the wells we acquired in December 2015.

Our ~~oil~~natural ~~and~~ gas sales ~~are primarily attributable to our properties in Kansas and Wyoming. Oil sales~~ for the three months ended ~~June~~September 30, 2016 and 2015, were $~~260~~20,~~574~~220 and $~~200~~22,~~029~~507, respectively, ana ~~increase~~decrease of $602,~~545~~287 or 3010.32%,. ~~due~~The ~~primarily~~average torealized ~~increased~~natural ~~sales~~gas ~~volumes~~prices, ~~which~~including ~~were~~proceeds ~~6,379~~from ~~barrels~~sales of ~~oil~~NGL's, ~~during~~for the three months ended ~~June~~September 30, 2016, ~~compared~~and ~~to 3~~2015,~~968~~ ~~barrels~~were of$1.94 ~~oil~~and ~~during~~$1.84 ~~the~~per ~~same~~Mcf, ~~period~~an inincrease ~~the~~of ~~prior~~$0.10 ~~year~~or 5.3%. The ~~effect~~impact on ~~our~~natural ~~oil~~gas sales ~~due~~in to the ~~increased~~current ~~sales~~year ~~volumes~~due ~~was~~to ~~an increase of $98,486. However,~~ the ~~average~~higher realized ~~oil~~prices ~~price~~resulted ~~during~~in ~~the~~increased ~~three~~natural ~~months~~gas ~~ended~~sales ~~June~~of ~~30, 2016, was~~ $~~40.85~~1,195 ~~which~~and ~~was $9.56 lower than~~ the ~~price~~decrease ~~per barrel of oil for the same period~~ in ~~the~~natural ~~prior~~gas ~~year,~~volumes ~~which~~resulted ~~was $50.41. This 19.0% decrease~~ in ~~price~~lower ~~negatively~~natural ~~impacted~~gas ~~our oil~~ sales by $373,~~941~~482. ~~The increase in our oil sales production was due to the wells we acquired in December 2015.~~

~~Our~~Lease ~~natural~~operating ~~gas~~expense ~~sales~~per Barrel of Oil Equivalent ("BOE") for the three months ended ~~June~~September 30, 2016 and 2015 were $~~17,200~~42.81 and $3435.96,~~531,~~ respectively, aan ~~decrease~~increase of $~~17,331~~6.85 per BOE or 5019.20%. ~~The~~Many ~~average~~of ~~realized~~the ~~natural~~wells ~~gas~~in ~~prices,~~our ~~including~~acreage ~~proceeds~~have ~~from~~been ~~sales~~producing offor ~~NGL's,~~a ~~for~~decade ~~the~~or ~~three~~longer ~~months~~and ~~ended~~the ~~June~~cost ~~30,~~of ~~2016~~workovers and ~~2015,~~normal ~~were~~maintenance ~~$1.67~~are ~~and~~charged ~~$2.33~~to ~~per~~expense ~~Mcf,~~in athe ~~decrease~~period ofthe ~~$0.67~~costs orare 28incurred.~~5%.~~ The ~~impact~~increase ~~on natural gas sales~~ in the ~~current~~cost ~~year~~per BOE was due primarily to ~~the~~a ~~lower~~workover ~~realized~~program ~~prices~~the ~~resulted~~company inimplemented ~~decreased~~during ~~natural~~the ~~gas~~third ~~sales~~quarter of ~~$7,479~~2016 ~~and~~related to the ~~decrease~~Wellstar acquisition we completed in ~~natural~~December ~~gas~~2015. LOE ~~volumes,~~for ~~which~~the ~~decreased~~three ~~4,489~~month ~~Mcf~~period orended September 30~~.3%~~, ~~resulted~~2016 inand a2015 ~~further~~was ~~reduction~~$313,086 ofand ~~natural~~$270,719, ~~gas~~which ~~sales~~was byan increase of $942,~~852~~367 or 15.6%.

Lease operating expense per Barrel of Oil Equivalent ("BOE") for the three months ended June 30, 2016 and 2015 were $25.30 and $30.77, respectively, a decrease of $5.47 or 17.8%. Many of the wells in our acreage have been producing for a decade or longer and the cost of workovers and normal maintenance are charged to expense in the period the costs are incurred. The decrease in the cost per BOE was due to increased production during the three month period ended June 30, 2016, and to the wells we acquired in December 2015, which have a lower average LOE. LOE for the three month period ended June 30, 2016 and 2015 was $204,897 and $198,096, which was a slight increase of $6,828 or 3.4%. The increase in LOE costs was due to the wells we acquired in December 2015.16

Production taxes for the three months ended ~~June~~September 30, 2016 and 2015 were $2119,~~953~~367 and $1929,~~374~~101, respectively, an ~~increase~~decrease of $29,~~579~~734 or 1333.34%. We generally expect absolute production tax expense to trend as a percentage with oil, gas, and NGL production revenue within each state we have operations. Production taxes as a percentage of revenue for the three months ended ~~June~~September 30, 2016 and 2015 were 78.91% and 811.25%,. ~~which~~Our production in Kansas and Nebraska has a blended production tax rate of approximately 4.4% and our Wyoming production is ~~consistent~~approximately ~~with~~13.0%; ~~what~~therefore, weas ~~would~~our ~~expect~~sales increase in Wyoming compared to Kansas and Nebraska the tax rate as a percentage of sales increases. We had more production in Kansas and Nebraska in 2016 compared to 2015 due to the Wellstar acquisition in December 2015; therefore, the tax rate as a percentage of revenue decreased.

Under successful efforts accounting, DD&A expense is separately computed for each producing field based on geologic and reservoir delineation. The capital expenditures for proved properties for each field compared to the proved reserves corresponding to each producing field determine a weighted average DD&A rate for current production. Future DD&A rates will be adjusted to reflect future capital expenditures and proved reserve changes in specific areas. Our DD&A expense for the three months ended ~~June~~September 30, 2016 and 2015 was $9677,000 and $~~116~~168,~~294~~782, a decrease of $2091,~~294~~782 or 1754.5%. This decrease was due primarily to a lower depletable cost basis of our oil and gas properties due to an impairment expense taken in December 2015 and March 2016.

~~Six~~Nine Months Ended ~~June~~September 30, 2016 and 2015

Our oil sales for the ~~six~~nine months ended ~~June~~September 30, 2016 and 2015 were $~~414~~633,~~557~~961 and $~~387~~617,~~178~~906, respectively, an increase of $2716,~~379~~055 or 72.16%. This increase was due to increased sales volumes, which were 1117,~~911~~490 barrels of oil during the ~~six~~nine months ended ~~June~~September 30, 2016, compared to 814,~~905~~400 barrels of oil during the same period in the prior year. The effect on our oil sales due to the increased sales volumes was an increase of $~~104~~112,~~622. However~~003, ~~the~~offset by lower average realized oil ~~price~~prices during the ~~six~~nine months ended ~~June~~September 30, 2016, ~~was $34.80,~~ which was $836.6725 ~~less~~ compared to $4342.4891 per barrel in 2015 for the same period. This 2015.05% decrease in price negatively impacted our oil sales by $7795,~~243~~948.

Our natural gas sales for the ~~six~~nine months ended ~~June~~September 30, 2016 and 2015 were $4565,~~418~~638 and $90112,~~047~~554, respectively, a decrease of $4446,~~629~~916 or 4941.67%. The average realized natural gas prices, including proceeds from sales of natural gas liquids, for the ~~six~~nine months ended ~~June~~September 30, 2016 and 2015, were $1.7983 and $2.5839 per Mcf, a decrease of $0.8056 or 3023.84%. The impact on natural gas sales in the current year due to the lower realized prices resulted in decreased natural gas sales of $2726,~~758~~333, which was further impacted by decreased natural gas volumes, 911,~~445~~237 Mcf or 2723.19% lower volumes, resulting in a reduction of natural gas sales of $1620,~~871~~583.

Lease operating expense for the ~~six~~nine months ended ~~June~~September 30, 2016 and 2015 were $~~487~~800,~~455~~541 and $~~414~~685,~~868~~587, which was an increase of $72114,~~587~~954 or 1716.58%. LOE per BOE for the ~~six~~nine months ended ~~June~~September 30, 2016 and 2015 were $3034.1912 and $2830.1982, respectively, an increase of $23.0030 or 710.17%. The increase in the cost per BOE was due to increased maintenance and chemical work performed during the three month period ended March 31, 2016, ~~in order to enhance production~~ and ~~curtail~~a ~~natural~~workover ~~decline~~program ~~curves. LOE~~we ~~per~~implemented ~~BOE~~in ~~for~~ the ~~three~~third ~~months~~quarter ~~ended~~of ~~June 30,~~ 2016, ~~was~~related ~~lower~~to ~~offsetting~~ the ~~high~~Wellstar ~~costs~~acquisition ~~during~~we ~~the~~completed ~~first~~in ~~quarter~~December ~~of the current fiscal year, as described above~~2015.

18Production taxes for the nine months ended September 30, 2016 and 2015 were $55,434 and $66,900, respectively, a decrease of $11,466 or 17.1%. We generally expect absolute production tax expense to trend as a percentage with oil, gas, and NGL production revenue within each state we have operations in. Production taxes as a percentage of revenue for the nine months ended September 30, 2016 and 2015 were 7.9% and 9.1%. Our production in Kansas and Nebraska has a blended production tax rate of approximately 4.4% and our Wyoming production is approximately 13.0%; therefore, as our sales increase in Wyoming compared to Kansas and Nebraska the tax rate as a percentage of sales increases. We had more production in Kansas and Nebraska in 2016 compared to 2015 due to the Wellstar acquisition in December 2015; therefore, the tax rate as a percentage of revenue decreased.

~~Production~~Our ~~taxes~~DD&A expense for the ~~six~~nine months ended ~~June~~September 30, 2016 and 2015 ~~were~~was $36328,~~067~~000 and $37476,~~799~~104, ~~respectively,~~ a decrease of $1148,~~732~~104 or 431.61%. WeThis ~~generally~~decrease ~~expect~~was ~~absolute~~due ~~production tax expense~~ to ~~trend as~~ a ~~percentage~~lower ~~with~~depletable ~~oil,~~base ~~gas,~~because ~~and~~of ~~NGL production revenue. Production taxes as~~ a ~~percentage~~write down of ~~revenue~~oil ~~for~~and ~~the~~gas ~~six~~properties ~~months~~at ~~ended~~December ~~June 30~~31, ~~2016~~2015 and ~~2015~~March ~~were~~31, ~~7.8% and 7.9%~~2016, ~~which~~against isimpairment ~~consistent~~expense, ~~with~~as ~~what~~well weas, ~~would~~an ~~expect.~~increase ~~Total~~in ~~oil~~the ~~and~~reserve ~~gas~~base ~~sales,~~related ~~excluding~~to the ~~sales~~acquisition of ~~oil~~additional ~~and~~producing ~~gas~~wells ~~properties,~~at ~~for~~December ~~the six months ended June 30~~31, ~~2016 and~~ 2015 ~~were 461~~,~~252,~~ which ~~was~~reduced ~~consistent with~~ the ~~same~~DD&A ~~period in the prior year at $481,166~~rate.

Our DD&A expense for the six months ended June 30, 2016 and 2015 was $251,000 and $307,322, a decrease of $56,322 or 18.3%. This decrease was due to a lower depletable base because of a write down of oil and gas properties at December 31, 2015 and March 31, 2016, against impairment expense, as well as, an increase in the reserve base related to the acquisition of additional producing wells at December 31, 2015, which reduced the DD&A rate.

We perform assessments of our long-lived assets to be held and used, including oil and gas properties, whenever events or circumstances indicate that the carrying value of those assets may not be recoverable. To the extent such assessments indicate a reduction of the estimated useful life or estimated future cash flows of our oil and gas properties, the carrying value may not be recoverable and therefore an impairment charge would be required to reduce the carrying value of the proved properties to their fair value.

The cash flow model we use to assess proved properties for impairment includes numerous assumptions. The primary factors that may affect estimates of future cash flows are (i) future reserve adjustments, both positive and negative, to proved reserves and appropriate risk-adjusted probable and possible reserves, (ii) results of future drilling activities, (iii) management's price outlook and (iv) increases or decreases in production costs and capital costs associated with those reserves. All inputs to the cash flow model are evaluated at each measurement date.

As a result of our proved property impairment assessments, we recognized a $252,000 noncash impairment charge to reduce the carrying values of our proved properties at March 31, 2016.

General and Administrative

Presented below is a summary of general and administrative expenses for the three and ~~six~~nine months ended ~~June~~September 30, 2016 and 2015:

Three Months ended

~~Six~~Nine Months ended

June 30,

September 30,

General and administrative expenses:

2016

2015

2016

2015

Director fees

10,000

1213,~~000~~333

2030,000

2235,~~000~~333

Investor relations

51,~~406~~097

730,~~465~~897

78,~~313~~410

1041,~~628~~525

Legal, auditing and professional fees

5623,~~713~~185

616,~~290~~458

85109,~~884~~069

7380,~~855~~313

Consulting fees - Related Parties

2414,~~232~~000

3643,~~000~~333

4054,732

83126,~~400~~733

Other administrative expenses

810,~~006~~103

2520,~~285~~699

2333,~~172~~275

4465,~~439~~138

Depreciation

143

~~285~~428

Total G&A Expense

~~104~~58,~~357~~385

~~142~~114,~~183~~863

~~177~~235,~~101~~486

~~234~~349,~~607~~470

Three Months Ended ~~June~~September 30, 2016 and 2015

General and administrative expenses decreased $3756,~~826~~478 or 2649.62% for the three month period ended ~~June~~September 30, 2016, compared to the same period in 2015. This reduction was primarily due to a decrease in related party consulting fees and other administrative expenses, offset by an increase in legal, auditing and professional fees. During 2015 there was a monthly charge of $10,000 charged to related party consulting fees under an agreement with DNR, whereby executive level expertise was provided for our existing and prospective oil and gas properties. The total monthly charge under the operating agreement was $18,000, of which $8,000 was allocated to lease operating expense and $10,000 was allocated to related party consulting fees. DNR is an affiliate of Charles B. Davis, an executive officer and director of the Company. We re-negotiated this agreement in 2016 and are no longer paying the $10,000 consulting fee in 2016 and are only paying the operating fee which increased to $13,000 compared to $8,000 in the prior year. ~~This~~Increased ~~$30,000~~accounting ~~reduction~~and ofconsulting ~~related~~services ~~party~~for ~~consulting~~our ~~expense~~Chief ~~was~~Financial ~~offset~~Officer byand ~~increased~~legal ~~accounting~~expenses ~~and~~offset ~~consulting~~this ~~services~~approximate ~~for~~$30,000 ~~our~~reduction ~~Chief~~of ~~Financial~~related ~~Officer~~party consulting expense. Other administrative expenses include D&O insurance, travel & entertainment expense and miscellaneous office expenses. These costs decreased primarily due to a new D&O policy that resulted in a significant cost savings compared to the same period in the prior year. Management continues to focus on reducing general and administrative expenses as a cost per BOE, which decreased $97.2128 or 47.7% to $127.8898 per BOE compared to $2215.0926 per BOE in the prior year.

19Nine Months Ended September 30, 2016 and 2015

~~Six~~General ~~Months~~and ~~Ended~~administrative ~~June~~expenses decreased $113,984 or 32.6% for the nine month period ended September 30, 2016, ~~and~~compared to the same period in 2015. This reduction was due to a decrease in related party consulting fees and other administrative expenses. The new consulting agreement with DNR was the main driver of this cost savings, as was the new D&O insurance policy. These reductions were offset by higher legal costs in the current year, which were related to litigation, general corporate and securities filings. The costs per BOE, which decreased $5.67 or 36.1% to $10.04 per BOE compared to $15.71 per BOE in the prior year.

General and administrative expenses decreased $57,506 or 24.5% for the six month period ended June 30, 2016, compared to the same period in 2015. This reduction was due to a decrease in related party consulting fees and other administrative expenses. The new consulting agreement with DNR was the main driver of this cost savings, as was the new D&O insurance policy. These reductions were offset by higher legal costs in the current year, which were related to general corporate and SEC matters. The costs per BOE, which decreased $4.97 to $10.97 per BOE compared to $15.94 per BOE in the prior year.

Interest Expense, net

Interest expense, net of interest income, for the ~~six~~nine months ended ~~June~~September 3130, 2016 and 2015 was $4470,~~952~~019 and $5887,~~680~~052, a decrease of $917,~~285~~033 or 1519.86%, ~~primarily~~ due to a decrease in the amount of debt outstanding compared to the same period the ~~last~~prior year. We recorded $58,~~972~~904 of interest expense to related parties during the ~~six~~nine ~~month~~months ~~period~~ ended ~~June~~September 30, 2016 and paid $1,~~340~~972 to one of the related parties. The remaining interest expense was to unrelated parties, of which we made payments of $3960,~~541~~080 during the ~~quarter~~nine months ended September 30, 2016.

Liquidity and Capital Resources

We have incurred significant net operating losses during the ~~six~~nine months ended ~~June~~September 30, 2016, and for the fiscal year ended December 31, 2015. We also had significant negative working capital at ~~June~~September 30, 2016, and we are currently in default with one of our creditors for which we have a note payable of $62,000. InWe ~~order to execute our drilling plans and to be in a position to seek to acquire additional interests in oil and gas properties that meet our objectives, we~~ need to obtain significant additional financing. This recent history of operating losses, negative working capital and defaults, along with low commodity prices, ~~may~~will likely adversely affect our ability to access the capital we need to continue operations on terms acceptable to us when such capital is needed. Historically, we have used a line of credit, preferred stock offerings and sales of oil and gas properties in order to fund our operations. In late 2015, we raised approximately $1.7 million through a private placement of our Series A2 Preferred Stock. We have successfully negotiated extensions with some of our key notes payable holders resulting in extending the due dates of the notes. Since 2011, we have sold various interests in some of our oil and gas properties, which have resulted in aggregate net proceeds from these sales of $6,377,000. Still, our ability to continue as a going concern is dependent upon the ability to successfully accomplish our business plan and continue to secure other sources of financing and attain profitable operations. The Company continues to pursue additional sources of financing but there can be no assurance that such financing will be completed on terms favorable to the Company, if at all.

We had a working capital deficit as of June 30, 2016, of approximately $1.1 million, compared to a working capital deficit of approximately $1.4 million at December 31, 2015. The decrease in our deficit was primarily due to a payment made to DNR related to a settlement agreement of approximately $300,000 that was included in accounts payable to DNR, and a decrease in our current notes payable due to executing some amendments on various notes payable that extended the due date making those related notes long term debt.18

We ~~used~~had ~~$369,504~~a inworking ~~operating~~capital ~~cash~~deficit ~~flow~~as ~~during~~of ~~the~~September 30, ~~six~~2016, ~~months~~of ~~ended~~approximately ~~June~~$1.2 30million, ~~2016~~ compared to ~~operating~~a ~~cash~~working ~~flow~~capital ~~used~~deficit of approximately $~~29,091during~~1.4 ~~the~~million ~~same~~at ~~period~~December 31, in2015. ~~the~~The ~~prior~~decrease ~~year.~~in ~~This~~our deficit was primarily ~~related~~due to ~~lower~~a ~~oil~~payment ~~and~~made ~~natural~~to ~~gas~~DNR ~~prices,~~related ~~which~~to ~~resulted~~a insettlement ~~lower~~agreement ~~revenues~~ of approximately $40300,000 ~~and~~that ~~due~~was toincluded ~~the~~in ~~payment~~accounts ofpayable ~~approximately~~to ~~$300~~DNR,~~000~~ and a decrease in our current notes payable due to ~~DNR~~executing ~~related~~some toamendments aon ~~settlement~~various ~~agreement~~notes inpayable ~~December~~that ~~2015~~extended the due date making those related notes long term debt.

~~Investing~~We ~~activities~~incurred ~~used~~negative ~~net~~ cash flow of $~~373~~434,226 ~~which~~from ~~was~~our ~~related~~operations toduring the ~~payment~~nine ofmonths ~~some~~ended ~~leasehold~~September ~~costs~~30, ~~and~~2016 ~~capital~~compared ~~additions~~ to ~~some~~negative ~~existing~~operating ~~wells~~cash inflow ~~which~~of we$61,572 ~~own~~during athe ~~very~~same ~~small~~period ~~working~~in ~~interest~~the inprior year. WeThis ~~used~~was ~~$43,116~~primarily ofrelated ~~cash~~to ~~during~~lower ~~the~~oil ~~six~~and ~~months~~natural ~~ended~~gas ~~June 30~~prices, ~~2015,~~which ~~related~~resulted toin ~~oil~~lower revenues of approximately $60,000 and ~~gas~~due ~~capital~~to ~~expenditures~~the payment of approximately $93300,~~116~~000 ~~offset~~due byto ~~the~~DNR ~~sale~~related ofto a ~~well,~~settlement ~~which~~agreement ~~generated~~in ~~proceeds~~December ~~of $50,000~~2015.

WeInvesting ~~had~~activities ~~$113,989~~used of net cash ~~provided~~of ~~by financing activities for the six months ended June 30, 2016, and~~ $47373,~~730~~ ~~provided~~which bywas ~~financing~~related ~~activities~~to ~~for~~ the ~~same~~payment ~~period~~of insome ~~the~~leasehold ~~prior~~costs ~~year.~~and ~~During~~capital ~~the~~additions ~~current year we entered into a short-term note payable with an unrelated party for net proceeds of $25,500~~ to ~~finance~~some ~~our~~existing ~~D&O~~wells ~~Insurance~~in ~~liability~~which ~~policy,~~ we ~~entered~~own ~~into~~ a ~~two~~very ~~year~~small ~~note~~working ~~payable~~interest ~~with~~in. anWe ~~unrelated~~used ~~party for~~ $~~100~~14,~~000,~~416 weof ~~made~~cash ~~principal~~during ~~payments~~the onnine ~~our~~months ~~notes~~ended ~~payable~~September ~~in the amount of $118~~30,~~002,~~ ~~we received $105~~2015,~~000~~ related to ~~the~~oil A2and ~~Preferred~~gas ~~Stock~~capital ~~issued~~expenditures ~~during the prior year, as well as, receiving proceeds~~ of $5093,~~000~~116 ~~for~~offset anby ~~additional~~the sale of 5a ~~shares of our A2 Preferred Stock and we paid $48~~well,~~509~~ inwhich ~~dividends~~generated toproceeds ~~our A2 Preferred Stock holders. In the prior year we drew down $60,000 on our line~~ of ~~credit and made principal payments of~~ $1250,~~270~~000.

20We had $172,273 of net cash provided by financing activities for the nine months ended September 30, 2016, and $47,342 provided by financing activities for the same period in the prior year. During the current year we entered into a short-term note payable with an unrelated party for net proceeds of $25,500 to finance our D&O Insurance liability policy, we entered into a two year note payable with three unrelated party's for net proceeds of $250,000, we made principal payments on our notes payable in the amount of $137,248, we received $105,000 related to the A2 Preferred Stock issued during the prior year, as well as, receiving proceeds of $50,000 for an additional sale of 5 shares of our A2 Preferred Stock and we paid $95,979 in dividends to our A2 Preferred Stock holders.

Off-Balance Sheet Arrangements

In connection with the related party acquisition of oil and gas properties in the third quarter of 2011, we acquired interests in certain geologic zones of the properties. This agreement contained several arrangements that would require us to pay certain amounts depending on certain thresholds met. However, on January 19, 2016, but effective December 31, 2015, we entered into a settlement agreement with the Sellers of these properties, whereby in consideration of the amounts indicated below, the parties (i) terminated Exhibits C and C-2 to the DNR and Tindall PSA for all purposes; (ii) extinguished all liabilities of the Company under Exhibit C of the DNR and Tindall PSA including $250,000, related to the increase in oil prices after the acquisition; (iii) agreed that the promissory note owed by us to DNR in the amount of $792,151 and accrued interest thereon was paid in full; and (iv) released each other against any and all claims which have been raised or could have been raised among them. Specifically, Exhibits C and C-2 to the DNR and Tindall PSA related to potential payments that would have been needed to be made by us in the event oil prices increased to certain levels and related to certain payments that would have been needed to be made by us in the event we sold certain properties purchased under the Purchase and Sale Agreement. Exhibits C and C-2 were terminated and extinguished (including any amounts owed thereunder including $250,000 under Exhibit C to the Purchase and Sale Agreement) in exchange for 25 fully paid, nonassessable restricted shares of our 7% Series A2 Convertible Preferred Stock. Consideration to pay the above promissory note in full consisted of us issuing to DNR 65 fully paid, nonassessable restricted shares of our 7% Series A2 Convertible Preferred Stock, and paying DNR $303,329 in cash, which was paid on January 19, 2016.

Item 3 - Quantitative and Qualitative Disclosures about Market Risk

The Company is a "Smaller Reporting Company" and is not required to provide or disclose the information required by this item.

Item 4 - Controls and Procedures

As of ~~June~~September 30, 2016, our Chief Executive Officer and Chief Financial Officer (the "Certifying Officers") conducted evaluations of our disclosure controls and procedures. As defined under Sections 13a-15(e) and 15d-15(e) of the Exchange Act, the term "disclosure controls and procedures" means controls and other procedures of an issuer that are designed to ensure that information required to be disclosed by the issuer in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the SEC's rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by an issuer in the reports that it files or submits under the Exchange Act is accumulated and communicated to the issuer's management, including the Certifying Officers, to allow timely decisions regarding required disclosure. Based on this evaluation, the Certifying Officers have concluded that our disclosure controls and procedures were not effective to ensure that material information is recorded, processed, summarized and reported by our management on a timely basis in order to comply with our disclosure obligations under the Exchange Act and the rules and regulations promulgated thereunder. As discussed in our Annual Report on Form 10-K for the year ended December 31, 2015, the ineffectiveness of our disclosure controls and procedures is due primarily to (i) our Board of Directors does not currently have any independent members that qualify as an audit committee financial expert, (ii) we have not developed and effectively communicated our accounting policies and procedures, (iii) our documentation of transaction in certain circumstances is not timely due to our limited staff and resources, and (iv) our controls over financial statement disclosures were determined to be ineffective.

Further, there were no changes in our internal control over financial reporting subsequent to ~~June~~September 30, 2016, and through the filing date that has materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II - OTHER INFORMATION

Item 1 - Legal Proceedings.

From time to time, the Company is a party to routine litigation and proceedings that are considered part of the ordinary course of its business. On September 29, 2016, a complaint was filed against the Company and two others in the Superior Court of Arizona, Maricopa County, entitled Eric Langan, Paul McNulty, Patricia Quick, Stony Point Fund, L.P., and Jeffrey H. Wallen, D.D.S., P.C. vs. Arête Industries, Inc., Don Prosser, and Charles Davis. The complaint alleges that defendants Prosser and Davis made certain material representations to the plaintiffs in connection with the alleged purchase by the plaintiffs of $555,000 in common stock of the Company. The complaint alleges that the alleged misrepresentations were deliberate and requests damages against all of the defendants to compensate the plaintiffs for their alleged injuries resulting from the alleged misrepresentations, including punitive damages. The Company has removed the case to the United States District Court for the District of Arizona and moved to dismiss the case, which motion has been fully briefed and itpending since December 23, 2016. The Company and the other defendants believe the action is entirely without merit and intend to vigorously defend the proceeding.

Item 1A - Risk Factors.

There have been no material changes to the risk factors set forth in our Annual Report on Form 10-K for the year ended December 31, 2015, as filed with the SEC on May 10, 2016. The risk factors in our Annual Report on Form 10-K for the year ended December 31, 2015, in addition to the other information set forth in this quarterly report, could materially affect our business, financial condition or results of operations. Additional risks and uncertainties not currently known to us or that we deem to be immaterial could also materially adversely affect our business, financial condition or results of operations.

Item 2 - Unregistered Sales of Equity Securities and Use of Proceeds.

Beginning in December 2015, the Company began privately offering up to 600 shares of its newly created 7% Series A2 Convertible Preferred Stock at a purchase price per share equal to $10,000 for aggregate consideration of up to $6,000,000. As of ~~June~~September 30, 2016, the Company had sold 182 shares ($1,820,000) for cash and issued 90 shares ($900,000) to DNR as part of the consideration for a settlement entered into with DNR during fiscal year ended December 31, 2015. The shares of 7% Series A2 Convertible Preferred Stock issued as described above were sold in reliance upon the exemption from registration provided by Section 4(2) of the Securities Act and Rule 506(b) promulgated thereunder. We issued 30,000 shares of restricted common stock related to a note agreement we entered into with an unrelated party on June 29, 2016, as loan closing costs valued at $3,600. We issued an additional 32,500 shares of our restricted common stock valued at $3,900 in July 2016 as loan closing costs, upon the formal closing of two other notes payable we entered into on June 30, 2016. These securities qualified for exemption under Rule 506 promulgated under Section 4(2) of the Securities Act because the issuance of securities by the Company did not involve a "public offering" based upon the following factors: (i) a limited number of securities were issued to a limited number of offerees with whom the Company had preexisting business relationships; (ii) there was no public solicitation in connection with any offers or sales of the securities; (iii) each offeree was an "accredited investor" as such term is defined by Rule 501 under the Securities Act; and (iv) the investment intent of the offerees.

Item 3 - Defaults upon Senior Securities.

None

Item 4 - Mine Safety Disclosures.

Not Applicable

Item 5 - Other Information.

None

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Item 6 - Exhibits

The following documents are filed as exhibits to this report on Form 10-Q or incorporated by reference herein.

31.1	Certification of the Principal Executive Officer pursuant to §302 of the Sarbanes-Oxley Act of 2002.

31.2	Certification of the Principal Financial Officer pursuant to §302 of the Sarbanes-Oxley Act of 2002.

32.1	Certification of the Principal Executive Officer pursuant to 18 U.S.C. Section 1350.

32.2	Certification of the Principal Financial Officer pursuant to 18 U.S.C. Section 1350.

101

The following materials are filed herewith: (i) XBRL Instance, (ii) XBRL Taxonomy Extension Schema, (iii) XBRL Taxonomy Extension Calculation, (iv) XBRL Taxonomy Extension Labels, (v) XBRL Taxonomy Extension Presentation, and (vi) XBRL Taxonomy Extension Definition. In accordance with Rule 406T of Regulation S-T, the information in these exhibits is furnished and deemed not filed or a part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, is deemed not filed for purposes of section 18 of the Exchange Act of 1934, and otherwise is not subject to liability under these sections and shall not be incorporated by reference into any registration statement or other document filed under the Securities Act of 1933, as amended, except as expressly set forth by the specific reference in such filing.

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ARÊTE INDUSTRIES, INC.

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.

By: /s/ Nicholas Scheidt, CEO

Nicholas L Scheidt, Principal Executive Officer

Dated: ~~February~~May 612, 2017

By: /s/ Tristan R. Farel

Tristan R Farel, Chief Financial Officer

Dated: ~~February~~May 612, 2017

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