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U.S. 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 30, 2015

☐    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: 001-32624

(Exact name of small business issuer as specified in its charter)

 

609 Castle Ridge Road, Suite 335

Austin, Texas  78746

(Address of Principal Executive Offices)   (Zip Code)

 

(512) 579-3560

(Issuer's Telephone Number, Including Area Code)

(former name, address and fiscal year, if changed since last report)

 

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the 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, if any, 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 ☒  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 definition of “large accelerated filer”, “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act (check one):

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

 

As of August 10, 2015, the number of shares outstanding of the Registrant's $.01 par value common stock was 8,880,101.

 

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PART I – FINANCIAL INFORMATION

Item 1.

Financial Statements

FieldPoint Petroleum Corporation

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS

 

See accompanying notes to these unaudited condensed consolidated financial statements

 

FieldPoint Petroleum Corporation

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

 

See accompanying notes to these unaudited condensed consolidated financial statements

 

FieldPoint Petroleum Corporation

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

See accompanying notes to these unaudited condensed consolidated financial statements

 

FieldPoint Petroleum Corporation

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

 

1.	Nature of Business, Organization and Basis of Preparation and Presentation

FieldPoint Petroleum Corporation (the “Company”, “FieldPoint”, “our”, or “we”) is incorporated under the laws of the state of Colorado.  The Company is engaged in the acquisition, operation and development of oil and natural gas properties, which are located in Louisiana, New Mexico, Oklahoma, Texas, and Wyoming.

The condensed consolidated financial statements included herein have been prepared by the Company, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission.  Certain information and footnote disclosures normally included in financial statements prepared in accordance with U.S. generally accepted accounting principles have been condensed or omitted.  However, in the opinion of management, all adjustments (which consist only of normal recurring adjustments) necessary to present fairly the financial position and results of operations for the periods presented have been made.  These condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and the notes thereto included in the Company's Form 10-K filing for the year ended December 31, 2014.

2.

Liquidity

 

As of June 30, 2015, the Company has a working capital deficit of approximately $5,761,000 because we had to reclass our line of credit as a current liability. The line of credit provides for certain financial covenants and ratios measured quarterly which include a current ratio, leverage ratio, and interest coverage ratio requirements.  The Company is out of compliance with our current ratio and our leverage ratio as of June 30, 2015. We are in the process of requesting an amended lending agreement or waiver from Citibank although there can be no assurances that it will be granted.  Unless and until such amendment or waiver is granted, Citibank could require us to pay off the note and we would need to secure alternative financing in the debt or equity market which, may or may not be available. Citibank is in a first lien position on all of our properties. We are current on all interest payments but expect our current borrowing base of $11,000,000 to be lowered. We have a positive net operating cash flow despite a net loss for the six months ended June 30, 2015.

 

3.	Recently Issued Accounting Pronouncements

In February 2015, the FASB issued ASU 2015-02, "Amendments to the Consolidation Analysis," which makes changes to both the variable interest model and the voting model, affecting all reporting entities involved with limited partnerships or similar entities, particularly industries such as the oil and gas, transportation and real estate sectors. In addition to reducing the number of consolidation models from four to two, the guidance simplifies and improves current guidance by placing more emphasis on risk of loss when determining a controlling financial interest and reducing the frequency of the application of related-party guidance when determining a controlling financial interest in a variable interest entity. The requirements of the guidance are effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period, with early adoption permitted. The adoption of ASU 2015-02 is currently not expected to have a material effect on our consolidated financial statements.

In April 2015, the FASB issued ASU 2015-03, "Simplifying the Presentation of Debt Issuance Costs", which requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability, consistent with the presentation of a debt discount. The guidance is effective on a retrospective basis for annual periods beginning after December 15, 2015, including interim periods within that reporting period, with early adoption permitted. The adoption of the updated standard is currently not expected to have a material effect on our consolidated financial statements and related disclosures.

See accompanying notes to these unaudited condensed consolidated financial statements

 

4.	Oil and Natural Gas Properties

 

No wells were drilled or completed during the three or six months ended June 30, 2015.

5.	Earnings Per Share

Basic earnings per share are computed based on the weighted average number of shares of common stock outstanding during the period.  Diluted earnings per share take common stock equivalents (such as options and warrants) into consideration using the treasury stock method.  The Company had 7,911,726 and 7,955,210 warrants outstanding with an exercise price of $4.00 at June 30, 2015 and 2014, respectively.  The dilutive effect of the warrants for the three and six months ended June 30, 2015 and 2014 is presented below.

 

7.	Related Party Transactions

The Company leased office space from the estate of its former president through January 2014 for $2,500 a month. Beginning February 1, 2014, the Company no longer rents office space from the estate.

During the six month period ended June 30, 2014, the Company paid a relative of a Board member $28,000 for petroleum engineering services. There were no comparable payments during the three and six month periods ended June 30, 2015.

8.

Debt

 

9.	Stockholders’ Equity

There were 7,911,726 warrants with an exercise price of $4.00 outstanding at June 30, 2015. There have been no warrants issued or exercised during the six months ended June 30, 2015. The weighted average expected life was 3.25 years at December 31, 2014, and was 2.75 years at June 30, 2015.

On June 24, 2015, the Board of Directors announced that it had approved a temporary reduction to the exercise price of its publicly traded warrants to $1.00 per share. This is a temporary modification for a period of 33 days commencing at the opening of trading on July 6, 2015, and ending at the close of trading on August 7, 2015. During this period, 734,716 warrants were exercised at a price of $1.00 per share for total proceeds of $734,716. Of this, $452,131 has been received by the Company and the remaining $282,585 is still being processed. Any and all warrants remaining unexercised after August 7, 2015, remain in full force and effect for the duration of their term with the initial exercise price of $4.00 per share.

 

As a signing bonus to his “at will” employment agreement, Phillip Roberson as President and CFO, is entitled to receive a total of 50,000 shares of common stock, of which 10,000 shares were immediately vested. An additional 10,000 shares were received and vested January 1, 2015, and again on July 1, 2015. Ten thousand shares will be received and vested at each of the six month anniversary dates of the commencement date until all are received and vested. The fair value of this stock grant was $275,000 of which $29,792 and $59,584 was recognized as non-cash stock compensation expense during the three and six months ended June 30, 2015, respectively. The remaining future expense related to this stock grant is $45,833 and is expected to be recognized over the weighted average expected life of less than one year.

 

10.	Commodity Derivatives

On May 13, 2015, we entered into the following commodity positions to hedge our oil production price risk, effective from June 1, 2015, to December 31, 2015. No commodity positions were outstanding at December 31, 2014. These positions were outstanding at June 30, 2015:

The following table summarizes the fair value of our open commodity derivatives as of June 30, 2015 and December 31, 2014:

				Fair Value
		Balance Sheet		June 30,				December 31,
		Location		2015				2014
Derivatives not designated as hedging instruments
Commodity derivatives		Current Assets		$	24,000			$	-

 

The following table summarizes the change in fair value of our commodity derivatives:

Unrealized gains and losses, at fair value, are included on our consolidated balance sheets as current or non-current assets or liabilities based on the anticipated timing of cash settlements under the related contracts.  Changes in the fair value of our commodity derivative contracts are recorded in earnings as they occur and included in other income (expense) on our consolidated statements of operations.  We estimate the fair values of collar contracts based on the present value of the difference in exchange-quoted forward price curves and contractual settlement prices multiplied by notional quantities.  We internally valued the option contracts using industry-standard option pricing models and observable market inputs.  We use our internal valuations to determine the fair values of the contracts that are reflected on our consolidated balance sheets.  Realized gains and losses are also included in other income (expense) on our consolidated statements of operations.

 

We are exposed to credit losses in the event of non-performance by the counterparties on our commodity derivatives positions and have considered the exposure in our internal valuations.  However, we do not anticipate non-performance by the counterparties over the term of the commodity derivatives positions. To estimate the fair value of our commodity derivatives positions, we use market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique.  These inputs can be readily observable, market corroborated or generally unobservable.  We primarily apply the market approach for recurring fair value measurements and attempt to use the best available information.  We determine the fair value based upon the hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and lowest priority to unobservable inputs (Level 3 measurement).  The three levels of fair value hierarchy are as follows:

·

Level 1 – Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. At June 30, 2015, we had no Level 1 measurements.

·

Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date.  Level 2 includes those financial instruments that are valued using models or other valuation methodologies.  These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and current market and contractual prices for the underlying instruments, as well as other relevant economic measures.  Our derivatives, which consist of commodity collars, are valued using commodity market data which is derived by combining raw inputs and quantitative models and processes to generate forward curves.  Where observable inputs are available, directly or indirectly, for substantially the full term of the asset or liability, the instrument is categorized in Level 2.  At June 30, 2015, all of our commodity derivatives were valued using Level 2 measurements.

·

Level 3 – Pricing inputs include significant inputs that are generally less observable from objective sources.  These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.  At June 30, 2015, we had no Level 3 measurements.

 

PART I

Item 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion should be read in conjunction with the Company’s Condensed Consolidated Financial Statements, and respective notes thereto, included elsewhere herein.  The information below should not be construed to imply that the results discussed herein will necessarily continue into the future or that any conclusion reached herein will necessarily be indicative of actual operating results in the future.  Such discussion represents only the best present assessment of the management of FieldPoint Petroleum Corporation.

General

FieldPoint Petroleum Corporation derives its revenues from its operating activities including sales of oil and natural gas and operating oil and natural gas properties.  The Company's capital for investment in producing oil and natural gas properties has been provided by cash flow from operating activities and from bank financing. The Company categorizes its operating expenses into the categories of production expenses and other expenses.

The Company completed drilling the Ranger 8A-1H well in the Taylor Serbin field in Texas in 2014. Production began February 1, 2014. The Company completed drilling the Ranger 11A-1H well in the Taylor Serbin field in Texas in 2014. Production began May 20, 2014.

In July 2014, the Company completed the Ranger 8A-2H and the Ranger 8A3-3H in Lee County, Texas. The Company has a 25% working interest and 18.75% net revenue interest in each well.  The net cost to drill and complete the wells was approximately $850,000 per well. The wells were successfully completed and are in production.

Results of Operations

 

Oil and natural gas sales revenues decreased 52% or $1,220,411 to $1,147,129 for the three-month period ended June 30, 2015, from the comparable 2014 period.  Average oil sales prices decreased 43% to $53.04 for the three-month period ended June 30, 2015, compared to $92.74 for the period ended June 30, 2014.  Average natural gas sales prices decreased to $2.89 for the three-month period ended June 30, 2015, compared to $4.25 for the period ended June 30, 2014.  Decreased oil and natural gas production accounted for a decrease in revenue of approximately $384,000. Lower commodity prices for oil and natural gas account for a decrease in revenue of approximately $836,000. We have temporarily suspended drilling and exploration activity due to low commodity prices and expect our volumes to decline in the coming quarters until drilling and exploration activities are re-established.

Lease operating expenses decreased 27% or $264,440 to $721,370 for the three month period ended June 30, 2015, from the comparable 2014 period.  This was primarily due to a decrease in non-critical workover activity.  Lifting costs per BOE decreased $3.02 to $29.05 for the 2015 period compared to $32.07 for the three months ended June 30, 2014, due mainly to less workover activity and general decrease in costs and lease operating expenses. We anticipate lease operating expenses to remain stable over the following quarters due to a cessation of new well activity as a result of low commodity pricing.

Depletion and depreciation decreased 29% or $179,700 to $443,800 for the three month period ended June 30, 2015, versus $623,500 in the 2014 comparable period.  This was primarily due to lower production volumes during the three months ended June 30, 2015.

General and administrative overhead cost decreased 20% or $72,675 to $283,307 for the three-month period ended June 30, 2015, from the three-month period ended June 30, 2014. This was primarily attributable to a decrease in board fees, consulting and professional services. At this time, the Company anticipates general and administrative expenses to remain stable or decrease slightly in the coming quarters.

 

Other expenses, net for the quarter ended June 30, 2015, were $71,962 compared to other expense, net of $48,010 for the quarter ended June 30, 2014.  The net increase in other expense was primarily due to the warrant modification expense of $66,124 offset by a realized gain on commodity derivatives of $25,234 and an unrealized gain on commodity derivatives of $24,000 in the three months ended June 30, 2015.

 

Results of Operations

Oil and natural gas sales revenues decreased 58% or $3,034,269 to $2,237,486 for the six month period ended June 30, 2015, from $5,271,755 for the comparable 2014 period. An overall decrease in oil and natural gas production accounted for a decrease in revenue of approximately $1,046,000 while a decrease in oil and natural gas commodity prices decreased revenue by approximately $1,988,000. Sales volumes decreased 21% on a BOE basis primarily due to production depletion which was not replaced due to a cessation of drilling activity. Average oil sales prices decreased $43.60 to $49.29 for the six month period ended June 30, 2015, compared to $92.89 for the six month period ended June 30, 2014.  Average natural gas sales prices decreased 48% to $2.84 for the six month period ended June 30, 2015, compared to $5.50 for the six month period ended June 30, 2014.  We anticipate volumes to decrease in the coming quarters primarily due to suspension of drilling and exploration activity due to low commodity prices and expect our volumes to decline in the coming quarters until drilling and exploration activities are re-established.

Depletion and depreciation expense decreased 34% to $950,600, compared to $1,449,000 for the comparable 2014 period.  This was primarily due to a decrease in production.

General and administrative overhead cost decreased 23% or $194,900 to $656,634 for the six month period ended June 30, 2015, from the six month period ended June 30, 2014.  This was attributable primarily to a decrease in salary expenses, board fees, and professional services.  In the coming quarters we anticipate general and administrative expenses to remain stable or decrease slightly.

 

Liquidity and Capital Resources

Cash flow provided by operating activities was $247,122 for the six month period ended June 30, 2015, as compared to $2,842,062 of cash flow provided by operating activities in the comparable 2014 period.  The decrease in cash flows from operating activities was primarily due to lower net income and depletion, a deferred tax benefit and changes in accounts payable.

Cash flow used in investing activities was $109,278 for the six month period ended June 30, 2015, and $2,938,140 in the comparable 2014 period due to fewer additions to oil and natural gas properties and equipment in the current period.

No cash flow was provided by financing activities for the six month period ended June 30, 2015. Cash flow provided by financing activities for the six month period ended June 30, 2014 included $500,000 from the draw on our line of credit plus $22,259 from the exercise of 5,565 of our outstanding publicly traded common stock purchase warrants at an exercise price of $4.00 per share.

We are out of compliance with our current ratio and our leverage ratio required by our line of credit as of June 30, 2015. We are in the process of requesting an amended lending agreement or waiver from Citibank although there can be no assurances that it will be granted.  Unless and until such amendment or waiver is granted, Citibank could require us to pay off the note and we would need to secure alternative financing in the debt or equity market which, may or may not be available. Citibank is in a first lien position on all of our properties. We are current on all interest payments but expect our current borrowing base of $11,000,000 to be lowered by the lender. We have a positive net operating cash flow for the year despite an earnings loss.

 

Subsequent Events

Under the temporary reduction to the exercise price of its publicly traded warrants as described in “Note 9 – Stockholder’s Equity”, 734,716 warrants were exercised at a price of $1.00 per share between July 6 and August 7, 2015. The Company has received $432,151 of the total proceeds of $734,716 as of August 12, 2015. The uncollected balance of $282,585 is still being processed but is expected to be received shortly.

 

PART I

Item 3.

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

We periodically enter into certain commodity price risk management transactions to manage our exposure to oil and natural gas price volatility.  These transactions may take the form of futures contracts, swaps or options.  All data relating to our derivative positions is presented in accordance with authoritative guidance.  Accordingly, unrealized gains and losses related to the change in fair value of derivative contracts that qualify and are designated as cash flow hedges are recorded as other comprehensive income or loss and such amounts are reclassified to oil and natural gas sales revenues as the associated production occurs.  Derivative contracts that do not qualify for hedge accounting treatment are recorded as derivative assets and liabilities at fair value in the consolidated balance sheet, and the associated unrealized gains and losses are recorded as current expense or income in the consolidated statement of operations.  While such derivative contracts do not qualify for hedge accounting, management believes these contracts can be utilized as an effective component of commodity price risk management activities.  On May 13, 2015, we entered into a commodity derivative position effective June 1, 2015. The collars have a floor of $55.00 per barrel and a ceiling of $70.00 for 200 barrels of oil per day from June 1, 2015, to December 31, 2015. We had a realized gain of $25,234 and a net unrealized gain of $24,000 on commodity derivative transactions during the six month period ending June 30, 2015. On March 27, 2014, we entered into a commodity derivative position effective April 1, 2014. The collars had a floor of $87.50 and a ceiling of $105.00 for 200 barrels of oil per day from April 1, 2014, to September 30, 2014. We had a realized loss of $882 and a net unrealized loss of $40,000 on commodity derivative transactions during the six month period ending June 30, 2014.

PART I

Item 4.

CONTROLS AND PROCEDURES

a)	Disclosure Controls and Procedures

Our Principal Executive Officer, Roger D. Bryant, and our Principal Financial Officer, Phillip H. Roberson, have established and are currently maintaining disclosure controls and procedures for the Company.  The disclosure controls and procedures have been designed to provide reasonable assurance that the information required to be disclosed by the Company in reports that it files under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC and to ensure that information required to be disclosed by the Company is accumulated and communicated to the Company's management as appropriate to allow timely decisions regarding required disclosure.

The Principal Executive Officer and the Principal Financial Officer conducted a review and evaluation of the effectiveness of the Company’s disclosure controls and procedures and have concluded, based on their evaluation as of the end of the period covered by this Report, that our disclosure controls and procedures are effective to provide reasonable assurance that information required to be disclosed in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC and to ensure that information required to be disclosed by the Company is accumulated and communicated to management, including our principal executive officer and our principal financial officer, to allow timely decisions regarding required disclosure and we refer you to Exchange Act Rule 13a-15(e).

b)	Changes in Internal Control over Financial Reporting

There have been no changes to the Company’s system of internal controls over financial reporting during the quarter ended June 30, 2015, that have materially affected, or are reasonably likely to materially affect, the Company’s system of controls over financial reporting.  As part of a continuing effort to improve the Company’s business processes, management is evaluating its internal controls and may update certain controls to accommodate any modifications to its business processes or accounting procedures.

 

c)	Limitations of Any Internal Control Design

Our principal executive and financial officers do not expect that our disclosure controls or internal controls will prevent all error and all fraud.  Although our disclosure controls and procedures were designed to provide reasonable assurance of achieving their objectives and our principal executive and financial officers have determined that our disclosure controls and procedures are effective at doing so, a control system, no matter how well conceived and operated, can provide only reasonable, not absolute assurance that the objectives of the system are met.  Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs.  Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within the Company have been detected.  These inherent limitations include the realities that judgments in decision-making can be faulty, and that breakdowns can occur because of simple error or mistake.  Additionally, controls can be circumvented if there exists in an individual a desire to do so.  There can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions.

 

PART II

OTHER INFORMATION

None.

None.

None.

None.

None.

None.

 

SIGNATURES

In accordance with the requirements of the Exchange Act, the registrant caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

 

 

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