Northern Oil and Gas (NOG) 8-K/A Financial Statements and Exhibits

Exhibit 99.3

Flywheel Bakken, LLC

Consolidated Balance Sheets

(Unaudited)

	June 30, 2019			December 31, 2018
Assets	(in thousands)
Current assets:
Cash and cash equivalents	$	825		$	1,416
Accounts receivable – oil, natural gas, and NGLs		13,739			18,880
Accounts receivable – affiliated parties		2,125			2,125
Commodity derivatives		550			9,471
Other current assets		737			618
Total current assets		17,976			32,510
Property and equipment:
Oil and gas properties, successful efforts method		314,280			302,551
Less: accumulated depreciation, depletion and amortization		(57,779	)		(42,098	)
Oil and gas properties, net		256,501			260,453
Other noncurrent assets:
Commodity derivatives		1,063			9,764
Other assets		253			631
Total assets	$	275,793		$	303,358
Liabilities and members’ equity
Current liabilities:
Accounts payable and accrued liabilities	$	10,458		$	7,211
Commodity derivatives		3,814			—
Other current liabilities		243			—
Total current liabilities		14,515			7,211
Long-term liabilities:
Revolving credit facility		134,591			137,885
Asset retirement obligations		1,016			974
Commodity derivatives		6,405			1,386
Other liabilities		1,336			—
Total long-term liabilities		143,348			140,245
Members’ capital		117,930			155,902
Total liabilities and members’ capital	$	275,793		$	303,358

The accompanying notes are an integral part of these consolidated financial statements.

Flywheel Bakken, LLC

Consolidated Statements of Operations

(Unaudited)

	Three Months Ended June 30, 2019			Three Months Ended June 30, 2018			Six Months Ended June 30, 2019			Six Months Ended June 30, 2018
	(in thousands)						(in thousands)
Revenues and other
Oil, natural gas, and NGL sales	$	29,385		$	48,343		$	59,483		$	95,210
Realized loss on derivatives, net		(2,219	)		(30,068	)		(2,607	)		(39,885	)
Total revenue		27,166			18,275			56,876			55,325
Operating costs and expenses
Lease operating expense		5,862			5,913			11,109			11,126
Transportation, gathering, and processing		3,799			5,564			7,977			9,694
Production and ad valorem taxes		2,505			3,958			4,777			8,004
Exploration and other expense		2			4			2			4
General and administrative expense		964			1,899			2,042			3,703
Depreciation, depletion, amortization, and accretion		5,855			8,946			15,723			19,732
Total operating costs and expenses		18,987			26,284			41,630			52,263
Other income (expense), net:
Other income		1			—			4			—
Interest expense		(1,789	)		(1,856	)		(3,390	)		(3,693	)
Unrealized gain (loss) on Commodity derivatives		9,083			—			(26,456	)		—
Unrealized loss on interest rate swap derivatives		(1,342	)		—			(2,094	)		—
Other income (expense), net:		5,953			(1,856	)		(31,936	)		(3,693	)
Net income (loss)	$	14,132		$	(9,865	)	$	(16,690	)	$	(631	)

The accompanying notes are an integral part of these consolidated financial statements.

Flywheel Bakken, LLC

Consolidated Statements of Members’ Capital

(Unaudited)

	Total
	(in thousands)
Balance at December 31, 2017	$	110,212
Net income		9,234
Balance at March 31, 2018		119,447
Distributions		(15,000	)
Net loss		(9,865	)
Balance at June 30, 2018	$	94,581
Balance at December 31, 2018		155,902
Distributions		(13,000	)
Shares repurchased		(262	)
Net loss		(30,822	)
Balance at March 31, 2019		111,818
Distributions		(8,020	)
Net income		14,132
Balance at June 30, 2019	$	117,930

The accompanying notes are an integral part of these consolidated financial statements.

Flywheel Bakken, LLC

Consolidated Statements of Cash Flows

(Unaudited)

	Six Months Ended June, 30 2019			Six Months Ended June, 30 2018
	(in thousands)
Operating activities
Net loss	$	(16,690	)	$	(631	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion, and amortization		15,682			19,695
Accretion of asset retirement obligations		41			37
Amortization of debt issuance costs		206			194
Loss on derivatives, net		30,956			39,885
Settlement paid on derivatives		(2,406	)		(10,257	)
Changes in assets and liabilities:
Decrease (increase) in accounts receivable		4,226			(17,350	)
(Increase) decrease in other current andnon-current assets		(258	)		108
Increase (decrease) in accounts payable and accrued liabilities		947			(4,143	)
Net cash provided by operating activities		32,704			27,538
Investing activities
Additions to oil and natural gas properties – operations		(8,638	)		(12,077	)
Additions to other property and equipment		—			(15	)
Net cash used in investing activities		(8,638	)		(12,092	)
Financing activities
Distributions to members, net of notes receivable		(20,895	)		(14,907	)
Shares repurchased		(262	)		—
Borrowings on revolving credit facility		23,000			26,100
Payments on revolving credit facility		(26,500	)		(28,800	)
Debt issuance costs		—			(35	)
Net cash used in by financing activities		(24,657	)		(17,642	)
Net decrease in cash and cash equivalents		(591	)		(2,196	)
Cash and cash equivalents at beginning of period		1,416			3,462
Cash and cash equivalents at end of period	$	825		$	1,265
Non-cash Items
Non-cash Distributions		(125	)		—
Net accrued additions to oil and natural gas properties		1,006			5,725

The accompanying notes are an integral part of these consolidated financial statements.

Flywheel Bakken, LLC

Notes to Consolidated Financial Statements

1. Organization and Business

Flywheel Bakken, LLC (“Flywheel Bakken” or the “Company”), previously Valorem Energy, LLC, a Delaware limited liability company, is a privately-owned exploration and production company formed on March 27, 2017 (“Inception”), to acquire, develop, and produce oil and gas properties. Flywheel Bakken’s wholly owned subsidiaries include Flywheel Bakken Operating, LLC (“Flywheel Bakken Operating”), previously Valorem Energy Operating, LLC, Valorem Energy Member, LLC (“Valorem Member”), Valorem Energy Management, LLC (“Valorem Management”), and VEN Bakken, LLC (“VEN Bakken”), all of which are Delaware limited liability companies.

Funding sources for the Company’s operations and acquisitions of properties are accomplished through member contributions by the Kayne Private Energy Income Fund, L.P. (“KPEIF”), affiliates of KPEIF, and members of management (“Management”), (collectively the “Members”), the utilization of its own cash resources, or any combination of these sources. The Company’s oil and gas properties are primarily located in the state of North Dakota with some minor interests in South Dakota and Montana.

2. Summary of Significant Accounting Policies

Principles of Consolidation

The consolidated financial statements include the accounts of Flywheel Bakken and its wholly owned subsidiaries, Flywheel Bakken Operating, Valorem Member, Valorem Management, and VEN Bakken. All significant intercompany balances and transactions have been eliminated in consolidation.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States (“U.S. GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Estimates of oil and gas reserves, as determined by independent petroleum engineers, are continually subject to revision based on price, production history, and other factors. Changes in the estimated oil and gas reserves utilized for depreciation, depletion, and amortization or the estimated future cash flows attributable to the reserves that are utilized for impairment assessments could have a significant impact on the future results of operations. Actual results could differ from those estimates.

Financial Instruments

The Company’s financial instruments are measured at fair value and consist primarily of cash and cash equivalents, an interest swap, commodity derivative contracts, accounts receivable, accounts payable, and the revolving credit facility. The Company’s derivative instruments are measured at fair value on a recurring basis, see Note 7 for further discussion. The carrying amount for the Company’s revolving credit facility is considered to be representative of fair market value due to the floating interest rate. The carrying amounts of the Company’s other financial instruments are considered to be representative of their fair market value due to their short-term nature.

The Company applies fair value accounting guidance to measure nonfinancial assets and liabilities, such as the acquisition or impairment of oil and natural gas properties and the inception value of asset retirement obligations. These assets and liabilities are subject to fair value adjustments only in certain circumstances and are not subject to recurring revaluations. See Notes 4 and 5 for further discussion.

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. A hierarchy exists for measuring fair value that prioritizes the inputs to valuation techniques used to measure fair value. This hierarchy consists of three broad levels:

Level 1: Valuations consist of unadjusted quoted prices in active markets for identical assets and liabilities. This level has the highest priority.

Level 2: Valuations rely on quoted prices in markets that are not active or observable inputs over the full term of the asset or liability.

Level 3: Valuations are based on prices of third-party or internal valuation models, which require inputs that are significant to the fair value measurement and are less observable and, thus, have the lowest priority.

The Company classified the commodity derivative contracts and interest swap contract outstanding as Level 2 in the fair value hierarchy based upon the data used to determine the fair values. See Note 7 for more information.

Asset retirement cost estimates are derived from historical costs, as well as management’s expectation of future cost environments. As there is no corroborating market activity to support the assumptions used, the Company has designated these liabilities as Level 3.

Derivatives

The Company is exposed to certain risks relating to its ongoing business operations, including risks related to commodity prices. As discussed more fully below, the Company uses derivative instruments primarily to manage commodity price risk. The derivatives are entered into with banks that participate in the revolving credit facility described in Note 6, and, therefore, there are no margin requirements. The revolving credit facility included an affirmative covenant requiring the Company to be 80% hedged through November 2022 for expected proved producing oil volumes only within 30 days of November 30, 2017, the closing date of the Company’s first acquisition of

properties. The Company is not subject to further hedging requirements under the revolving credit facility after November 30, 2022. All contracts have historically settled with cash and do not require the delivery of physical volumes. The Company does not intend to issue or hold derivative financial instruments for speculative trading purposes which are restricted by the revolving credit facility.

In conjunction with the acquisitions of oil and gas properties, the Company entered into derivative financial instruments with respect to a portion of its oil production to hedge future prices received. The instruments are used to manage the inherent uncertainty of future revenues resulting from commodity price volatility. Additionally, in conjunction with the financing of the acquisitions, the Company entered into an interest rate swap to manage the risk of interest rate volatility associated with the variable rate debt obtained to finance the acquisitions. The Company’s derivative financial instruments consist of fixed-price swaps for oil and an interest rate swap. Under the terms of the price swaps, the Company receives a fixed-price for its production and pays a variable market price to the contract counterparty.

All derivative financial instruments are recognized at their current fair value as either assets or liabilities in the balance sheets. Changes in the fair value of these derivative financial instruments are recorded in earnings. Cash settlements with counterparties are also recorded in earnings. Cash settlements to which the Company is entitled are accrued in other current assets, and cash settlements the Company is obligated to pay are included in other current liabilities in the accompanying consolidated balance sheets. See Note 7 for further discussion.

Cash and Cash Equivalents

The Company considers all highly liquid investments with original maturities of 90 days or less to be cash equivalents. The Company currently maintains no cash equivalents or investments as available cash is used to pay down the revolving credit facility.

Oil and Gas Properties

The Company follows the successful efforts method of accounting for its oil and gas properties; accordingly, exploration costs, other than the cost of drilling exploratory wells, are charged to expense as incurred. The costs of drilling exploratory wells are capitalized, pending determination of whether the wells discover proved commercial reserves. If proved commercial reserves are not discovered, such drilling costs are expensed. Other exploration costs, including geological and geophysical costs and delay rentals on unproved leaseholds, are charged to exploration expense as incurred. The costs of all development wells and related equipment used in the production of oil and gas are capitalized. Costs to operate and maintain field equipment are expensed as incurred.

Unproved oil and gas properties are periodically assessed for impairment, and any impairment is charged to expense. The costs of properties determined to be productive are transferred to proved oil and gas properties.

Proceeds from immaterial sales of properties are credited to property costs, and a gain or loss is recognized when a significant portion of an amortization base is sold or abandoned. During the periods ended June 30, 2019 and 2018, there were no sales of properties. On April 18, 2019, the Company entered into an agreement to sell all of the Company’s oil and gas properties and associated working capital for approximately $310 million, subject to normal purchase price adjustments. The closing and effective date of this transaction occurred on July 1, 2019.

Depletion, depreciation, and amortization of the cost of proved oil and gas properties and well equipment is calculated using theunit-of-production method. The reserve base used to calculate depletion, depreciation, and amortization is the sum of proved developed reserves and proved undeveloped reserves for leasehold acquisition cost and the cost to acquire proved properties. The reserve base used to calculate depletion, depreciation, and amortization for development costs is proved developed reserves. Estimated future dismantlement, restoration, abandonment cost, and net salvage values are taken into account.

The Company reviews its proved oil and gas properties for impairment at least annually or whenever events or changes in circumstances indicate that the carrying amounts of such properties may not be recoverable. If it is determined that a property’s estimated future net cash flows will not be sufficient to recover its carrying amount, an impairment charge is recognized to reduce the carrying amount of the asset to its estimated fair value by discounting anticipated future net cash flows.

Asset Retirement Obligations

A liability for an asset’s retirement is recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. The corresponding cost is capitalized as part of the carrying amount of the related long-lived asset. The liability is accreted to its then-present value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded balance, a gain or loss is recognized.

Revenue Recognition

Oil and natural gas sales are recorded using the sales method, whereby the Company recognizes revenue based upon the amount of oil and gas sold and delivered to product purchasers on its behalf.

The Company’s revenues are derived principally from uncollateralized sales to customers in the oil and gas industry; therefore, the Company’s customers may be similarly affected by changes in economic and other conditions within the industry. The Company has experienced no credit losses on such sales.

Debt Issuance Costs

The Company incurred legal and bank fees in connection with obtaining the revolving credit facility, which was entered into on November 30, 2017. The fees were capitalized and are being amortized to interest expense over the term of the revolving credit facility utilizing the interest method. Debt issuance costs are included as a reduction to debt in the accompanying consolidated balance sheet. Amortization of debt issuance costs is included in interest expense in the accompanying consolidated statement of operations. When debt is retired before maturity, or modifications significantly change the cash flows, the related unamortized costs are expensed. See Note 6 for more information.

Long-Term Incentive Compensation

In March 2017, the Company created and authorized the issuance of up to 3,000,000 Series B Units (“Incentive Units”). To date, approximately 75% of the Series B units have been issued to employees. Series B Unit holders are not required to make cash capital contributions in return for Series B Units; rather, the Incentive Units are issued in consideration of services rendered and to be rendered by the holders for the benefit of the Company. The Incentive Units were determined to be profit interest awards and are within the scope of Accounting Standards Codification (ASC) 710,Compensation – General. See Note 12 for further discussion on the Incentive units.

Recent Accounting Pronouncements

In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”)2014-09,Revenue from Contracts with Customers (Topic 606). ASU2014-09 supersedes most of the existing revenue recognition requirements in U.S. GAAP and requires (i) an entity to recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled to in exchange for those goods or services and (ii) requires expanded disclosures regarding the nature, amount, timing, and certainty of revenue and cash flows from contracts with customers. The ASU will be effective for annual and interim reporting periods beginning after December 15, 2018. The ASU allows for either full retrospective adoption, meaning the standard is applied to all periods presented in the financial statements, or modified retrospective adoption, meaning the standard is applied only to the most current period presented. The Company is currently evaluating the impact this ASU will have on its consolidated financial position, results of operations, or cash flows. The company’s adoption of ASU2014-09 is not expected to have a material impact.

In February 2016, the FASB issued ASU2016-02,Leases (Topic 842). ASU2016-02 requires lessees to recognize a lease liability and aright-of-use asset for all leases with a term greater than 12 months on the balance sheet, including operating leases. The provisions of ASU2016-02 also modify the definition of a lease and outline the requirements for recognition, measurement, presentation, and disclosure of leasing arrangements by both lessees and lessors. This ASU is effective for financial statements issued for annual periods beginning after December 15, 2019, and for interim periods within annual periods beginning after December 15, 2020. The Company has not yet determined what the effects of adopting this updated ASU will be on its consolidated financial statements. The company’s adoption of ASU2016-02 is not expected to have a material impact.

3. Income Taxes

The Company is not a taxpaying entity for federal or state income tax purposes, and, accordingly, it does not recognize any expense for such taxes. The income tax liability resulting from the Company’s activities is the responsibility of the Members. In the event of an examination of the Company’s tax return, the tax liability of the Members could be changed if an adjustment of the Company’s income or loss is ultimately sustained by taxing authorities.

4. Oil and Gas Properties

A summary of oil and gas properties is presented as follows:

	June 30, 2019			December 31, 2018
	(in thousands)
Oil and gas properties and equipment:
Undeveloped leasehold costs	$	56,600		$	56,600
Lease and well equipment		44,379			41,706
Developed leasehold and intangible drilling costs		213,301			204,245
		314,280			302,551
Accumulated depreciation, depletion, and amortization		(57,779	)		(42,098	)
	$	256,501		$	260,453

5. Asset Retirement Obligations

A summary of the Company’s asset retirement obligations is presented as follows:

	For the six months ended June 30, 2019		For the year ended December 31, 2018
	(in thousands)
Balance at beginning of period	$	974	$	857
Liabilities incurred		1		44
Accretion expense		41		73
Liabilities settled		—		—
Balance at end of period	$	1,016	$	974

6. Indebtedness

The Company had the following long-term debt outstanding:

	June 30, 2019			December 31, 2018
	(in thousands)
Revolving credit facility – Long-term	$	136,000		$	139,500
Debt issuance costs		(1,409	)		(1,615	)
Total revolving credit facility	$	134,591		$	137,885

Revolving Credit Facility

On November 30, 2017, the Company entered into a $500.0 million revolving credit facility between JPMorgan Chase Bank, N.A., Citigroup Global Markets, Inc., and Wells Fargo Securities, LLC, with JPMorgan Chase Bank, N.A. serving as administrative agent (collectively the “Banks”). The revolving credit facility is secured by substantially all of the Company’s oil and gas assets and matures on November 30, 2022.

The Banks established an initial borrowing base of $160.0 million under the $500.0 million revolving credit facility, subject to semiannual redeterminations based on the Banks’ evaluation of the Company’s oil and gas reserves. Outstanding borrowings under the revolving credit facility accrue interest at the London Interbank Offered Rate (“LIBOR”) plus a margin of 2.25%–3.25% that varies based on the utilization of the facility. The unused portion of the borrowing base is subject to a commitment fee ranging from 0.375% to 0.500% paid per quarter based on the utilization percentage of the borrowing base.

On April 23, 2019, the Company entered into Amendment No. 2 to the revolving credit facility, which established an updated borrowing base of $160.0 million under the $500.0 million revolving credit facility, based on the Banks’ evaluation of the Company’s oil and gas reserves. The outstanding balance on the revolving credit facility as of June 30, 2019, was $136.0 million, leaving $24.0 million of borrowing capacity available under the current borrowing base. The Company incurred and paid interest expense of $3.2 million and $3.5 million at June 30, 2019 and 2018, respectively.

The credit agreement also provides for the issuance of letters of credit, limited to the lesser of $25.0 million or availability under the credit agreement. There were no letters of credit outstanding at June 30, 2019.

Amortization of debt issuance costs totaled $0.2 million at June 30, 2019 and 2018. The Company had total unamortized debt issuance costs of $1.4 million and $1.7 million at June 30, 2019 and 2018, respectively, of which $0.4 million is expected to be amortized to interest expense each year over the next four years.

Debt Covenants and Maturity

The revolving credit facility agreement contains certain financial and nonfinancial covenants that limit the Company’s ability to, among other things, pay cash dividends, incur additional debt, sell assets, enter into certain hedging contracts, merge, consolidate, or make certain investments. In addition, the Company is required to maintain a ratio of EBITDAX to total debt (each as defined in the credit agreement) not to exceed 4.0 to 1.00 and a current ratio (as defined by the revolving credit facility) of not less than 1.00 to 1.00, both of which commenced with the fiscal quarter ending March 31, 2018. At June 30, 2019, the Company was in compliance with debt covenants.

7. Derivative Instruments

The Company uses financial instruments to manage its exposure to market fluctuations in the price of crude oil and interest rates. The Company’s general strategy is to mitigate oil price risk with fixed price swaps and to hedge interest rate risk with swaps. The Company entered into fixed price swaps during the periods ended June 30, 2019 and December 31, 2018, to reduce price risk exposure related to sales of oil. The Company also entered into an interest rate swap to reduce exposure to floating interest rates.

At June 30, 2019 and December 31, 2018, the Company’s derivative instruments consisted of the following:

• Interest rate swap – The Company utilized a notional amount interest rate swap contract to manage the interest rate risk. The Company’s interest rate swap contract serves to mitigate rate risk exposure by converting a portion of the Company’s monthly floating rate on its borrowings under its revolving credit facility to monthly fixed-rate payments.

• Fixed-price swaps – The Company receives a fixed price and pays a floating market price to the counterparty for a specified volume of the hedged commodity.

The Company’s derivative instruments as of June 30, 2019 were as follows:

	Oil Swaps (NYMEX/WTI indexed)
Period	Volumes (Bbls)		Weighted- Average Price ($/Bbl)
2019		726,575		56.17
2020		1,365,414		54.18
2021		1,002,074		51.08
2022		872,864		51.15
	Interest Rate Swaps
Period	Notional Amount (thousands)		Weighted- Average Fixed Rate
2019	$	75,000		2.09
2020		75,000		2.21
2021		75,000		2.27
2022		75,000		2.33

The Company’s derivative instruments as of December 31, 2018 were as follows:

	Oil Swaps (NYMEX/WTI indexed)
Period	Volumes (Bbls)		Weighted- Average Price ($/Bbl)
2019		1,479,146		53.70
2020		1,184,414		52.08
2021		1,002,074		51.08
2022		872,864		51.18
2023		666,470		60.53

	Interest Rate Swaps
Period	Notional Amount (thousands)		Weighted- Average Fixed Rate
2019		75,000		2.09
2020		75,000		2.21
2021		75,000		2.27
2022		75,000		2.33

The Company has not elected to designate its derivative instruments as cash flow hedging instruments; therefore, the changes in fair value are recognized each period in earnings as a component of revenue. The contracts are placed with major financial institutions deemed to be of high credit, each of which is a party to the revolving credit facility.

The following table summarizes the fair value, fair value hierarchy and location of each classification of the derivative instruments recorded in the consolidated balance sheet at June 30, 2019 and December 31, 2018, respectively:

	As of June 30, 2019
Consolidated Balance Sheet Classification (in thousands)	Gross Fair Value (Level 2)			Net Fair Value Presented in Consolidated Balance Sheet (Level 2)
Short-term commodity derivative asset	$	550		$	550
Short-term interest swap derivative asset1		22			22
Short-term commodity derivative liability		(3,814	)		(3,814	)
Short-term interest swap derivative liability2		(243	)		(243	)
Long-term commodity derivative asset		1,063			1,063
Long-term commodity derivative liability		(6,405	)		(6,405	)
Long-term interest rate derivative liability3		(1,336	)		(1,336	)
Total derivative contracts	$	(10,163	)	$	(10,163	)

¹  Short-term interest swap derivative asset is included within Other Current Assets on the Consolidated Balance Sheet.

²  Short-term interest swap derivative liability is included within Other Current Liabilities on the Consolidated Balance Sheet.

³  Long-term interest swap derivative liabilities is included within Other Liabilities on the Consolidated Balance Sheet.

	As of December 31, 2018
Consolidated Balance Sheet Classification (in thousands)	Gross Fair Value (Level 2)			Net Fair Value Presented in Consolidated Balance Sheet (Level 2)
Short-term commodity derivative asset	$	9,471		$	9,471
Short-term interest swap derivative asset		326			326
Long-term commodity derivative asset		9,764			9,764
Long-term interest swap derivative asset		211			211
Long-term commodity derivative liability		(1,386	)		(1,386	)
Total derivative contracts	$	18,386		$	18,386

The following table summarizes gains and losses related to the derivatives reflected in the consolidated statement of operations for the six months ended June 30, 2019 and 2018, respectively.

	For the six months ended June 30, 2019			For the six months ended June 30, 2018
	(in thousands)
Commoditymark-to-market gains/(losses)	$	(26,456	)	$	(29,628	)
Commodity settlements paid		(2,607	)		(10,261	)
Interest swapmark-to-market gains/(losses)		(2,094	)		—
Interest swap settlements paid		200			4
Total gain/(loss) on derivative instruments	$	(30,957	)	$	(39,885	)

¹  Interest swapmark-to-market and settlements paid are included within Other income on the Consolidated Statement of Operations.

Concentration of Credit Risk

By using derivative instruments that are not traded on an exchange, the Company exposes itself to credit risk from its counterparties. Credit risk is the risk of loss from counterparties not performing under the terms of the derivative instrument. When the fair value of a derivative instrument is an asset, the counterparty is expected to owe the Company, which creates credit risk. To minimize the credit risk in derivative instruments, the Company enters into derivative contracts only with counterparties that are creditworthy financial institutions that are parties to the revolving credit facility, which were also deemed by management as competent and competitive market-makers. Refer to Note 2 for additional information on the valuation of derivative assets and liabilities.

8. Risks and Uncertainties

Historically, the market for oil and natural gas has experienced significant price fluctuations. Prices are impacted by supply and demand, both domestic and international; seasonal variations caused by changing weather conditions; political conditions; governmental regulations; the availability, proximity, and capacity of gathering systems for natural gas and numerous other factors. Increases or decreases in prices received could have a significant impact on the Company’s future results of operations, reserves estimates, and financial position. The Company has certain commodity swap contracts in place with three counterparties to reduce its exposure to changes in commodity prices.

Estimating oil and gas reserves is complex and is not exact because of the numerous uncertainties inherent in the process. The process relies on interpretations of available geological, geophysical, engineering, and production data. The extent, quality, and reliability of both the data and the associated interpretations of that data can vary. The process also requires certain economic assumptions, including, but not limited to, oil and gas prices, drilling and operating expenses, capital expenditures, and taxes. Actual future production, oil and gas prices, revenues, taxes, development expenditures, operating expenses, and quantities of recoverable oil and gas most likely will vary from the Company’s estimates. Any significant variance could materially affect the Company’s future results of operations, reserves estimates, and financial position.

9. Commitments and Contingencies

All of the Company’s operations are subject to federal, state, and local environmental regulations. To the best of management’s knowledge, the Company is in compliance with such laws and regulations.

The Company is subject to potential lawsuits involving a variety of claims arising in the ordinary course of business. The Company also may be required to remove or mitigate the effects on the environment of the placement, storage, disposal, or release of certain chemical, mineral, and petroleum substances at various active and inactive sites. The Company regularly assesses the need for accounting recognition or disclosure of contingencies. In the case of all known contingencies (other than those related to income taxes), a liability is accrued when the loss is probable, and the amount is reasonably estimable. If a range of the amounts can be reasonably estimated, but no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. These liabilities are not reduced for potential insurance or third-party recoveries. If applicable, receivables are accrued for probable insurance or other third-party recoveries.

10. Capital Structure

Initial funding for the Company was obtained by issuing common membership interests in the Company (“Series A Units”) at a purchase price of $1,000 per Series A Unit up to a total of approximately 301,000 units. The Company’s Limited Liability Company (“LLC”) Agreement provides that the Company use the proceeds from the sale of the Series A Units for the acquisition and development of oil and gas properties, capital expenditures, working capital, and general Company purposes.

Management of its business affairs resides with the Company. Transfer of Series A Unit interests is only permitted if certain conditions specified in the LLC Agreement are met and is subject to approval of the Board of Directors.

Available cash flow after meeting operating requirements, property acquisition(s), and debt repayments may be used to make distributions to the partners according to their respective ownership interests.

As of June 30, 2019, approximately 131,000 Series A Units had been issued.

11. Affiliated-Party Transactions

On August 27, 2018, Valorem Energy, LLC entered into an Assignment Agreement with Flywheel Energy, LLC; Kayne Private Energy Income Fund, L.P.; and Kayne Private Energy Income Parallel Fund, L.P. whereby a specialone-time $2.2 million contribution was approved from Flywheel Energy, LLC, an affiliated company.

Effective as of September 1, 2018, Flywheel Bakken entered into an Amended and Restated Management Agreement with Flywheel Energy Management, LLC and Flywheel Energy, LLC, whereby Flywheel Energy Management, LLC provides certain management services to Flywheel Bakken. In accordance with these services, Flywheel Bakken agreed to reimbursement Flywheel Energy Management, LLC for all direct costs, and an allocated portion of indirect costs attributable to the business. Additionally, Flywheel Energy Management, LLC and Flywheel Energy, LLC agreed to reimburse Flywheel Bakken for direct costs, and an allocated portion of indirect costs attributable to the businesses. Total costs to be reimbursed by Flywheel Energy, LLC incurred in 2018 were $2.6 million. Net reimbursements received by Flywheel Bakken in 2019 were $1.0 million. The remaining amount due is shown on the balance sheets as accounts receivable – affiliate.

Management investors have the opportunity to borrow and invest in the Company amounts equal to their cash equity contributions. The loans are recorded as notes receivable and shown on the balance sheets as other assets. Interest is charged at the lowest Internal Revenue Service rate in effect. Repayment and interest payments occur when equity distributions are made. Amounts due from management were $0.2 million and $0.7 million at June 30, 2019 and 2018, respectively.

12. Incentive Units

On March 27, 2017 (the “Grant date”), a total of 3,000,000 incentive units, made up of all Series B Units, were created and authorized for issuance by the Members to employees. The Series B Units are considered a profits interest and are accounted for under the deferred compensation guidance in ASC 710,Compensation – General. These Series B Units do not represent a legal form of equity as there is no initial investment required to obtain the Series B Units. While the Series B Units allow employees to receive a portion of distributable cash after the Series A Members achieve certain returns on their contributions, the Series B Units arenon-voting and subordinate to debt and Series A Units based on the waterfall distribution.

At December 31, 2018, management did not consider it probable that either (i) the payout thresholds necessary to trigger distributions to Series B Unitholders would be achieved or (ii) that a triggering event that would lead to full vesting of the Series B Units would occur. Therefore, management has assessed the present value of expected future benefits associated with the Series B Units to be zero at December 31, 2018.

13. Subsequent Events

On April 18, 2019, the Company entered into an agreement to sell all of the Company’s oil and gas properties and associated working capital for approximately $310 million, subject to normal purchase price adjustments. The closing and effective date of this transaction occurred on July 1, 2019.

Subsequent events have been evaluated through September 12, 2019, the date the consolidated financial statements were available to be issued.