1.	Summary of Significant Accounting Policies

Organization and Nature of Operations

FieldPoint Petroleum Corporation (the "Company", "we" or "our") is incorporated under the laws of the state of Colorado. We are engaged in the acquisition, operation and development of oil and natural gas properties, which are located in Louisiana, New Mexico, Oklahoma, South Central Texas and Wyoming as of December 31, 2012 and 2011.

Consolidation Policy

Our consolidated financial statements include the accounts of the Company and its wholly owned subsidiaries, Bass Petroleum, Inc., and Raya Energy Corp. All material intercompany accounts and transactions have been eliminated in consolidation.

Cash and Cash Equivalents

We consider all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents. At times, we maintain deposit balances in excess of FDIC insurance limits. We have not experienced any losses in such accounts and believe we are not exposed to any significant credit risk on cash and cash equivalents.

Certificates of Deposit

Certificates of deposit have original maturities ranging from three months to one year and are recorded at fair value on the balance sheet in current assets. Changes in fair value during the period are classified as realized or unrealized holding gains in other income.

Oil and Natural Gas Properties

Our oil and natural gas properties consisted of the following at December 31:

	2012			2011
Mineral interests in properties:
Unproved properties	$	850,000		$	850,000
Proved properties		20,432,676			20,410,676
Wells and related equipment and facilities		10,927,576			6,356,252
Total costs		32,210,252			27,616,928
Less accumulated depletion and depreciation		(12,378,889	)		(10,088,699	)
	$	19,831,363		$	17,528,229

We follow the successful efforts method of accounting for our oil and natural gas producing activities. Costs to acquire mineral interests in oil and natural gas properties, to drill and equip exploratory wells that find proved reserves, to drill and equip development wells and related asset retirement costs are capitalized. Costs to drill exploratory wells are capitalized pending determination of whether the wells have found proved reserves. If we determine that the wells have not found proved reserves, the costs are charged to expense. There were no exploratory wells capitalized pending determinations of whether the wells found proved reserves at December 31, 2012 or 2011. Geological and geophysical costs, including seismic studies and costs of carrying and retaining unproved properties are charged to expense as incurred.

We capitalize interest on expenditures for significant exploration and development projects that last more than six months while activities are in progress to bring the assets to their intended use. Through December 31, 2012, we have capitalized no interest costs because our exploration and development projects generally last less than six months. Costs to maintain wells and related equipment are charged to expense as incurred.

On the sale or retirement of a complete unit of a proved property, the cost and related accumulated depletion and depreciation are eliminated from the property accounts, and the resulting gain or loss is recognized. On the sale of a partial unit of proved property, the amount received is treated as a reduction of the cost of the interest retained.

Capitalized amounts attributable to proved oil and natural gas properties are depleted by the unit-of-production method of proved reserves using the unit conversion ratio of 6 Mcf of gas to 1 bbl of oil. Depletion and depreciation expense for oil and natural gas producing property and related equipment was $2,086,000 and $1,115,000 for the years ended December 31, 2012 and 2011, respectively.

Unproved oil and natural gas properties that are individually significant are periodically assessed for impairment of value, and a loss is recognized at the time of impairment by providing an impairment allowance. No impairment of unproved properties was recorded during the years ended December 31, 2012. An impairment of unproved properties of $119,771 was recorded during the year ended December 31, 2011.

Capitalized costs related to proved oil and natural gas properties, including wells and related equipment and facilities, are evaluated for impairment based on an analysis of undiscounted future net cash flows. If undiscounted cash flows are insufficient to recover the net capitalized costs related to proved properties, then we recognize an impairment charge in income from operations equal to the difference between the net capitalized costs related to proved properties and their estimated fair values based on the present value of the related future net cash flows, which is a non-recurring fair value measurement classified as Level 3 in the fair value hierarchy. We recorded an impairment of $204,190 on the Loving property during the year ended December 31, 2012 on our proved oil and natural gas properties. We recorded impairment of $390,000 on the Loving property, $9,741 on the Stauss property, and $837,827 on the South Vacuum property for a total of $1,237,568 on our proved oil and natural gas properties during the year ended December 31, 2011.

On the sale of an entire interest in an unproved property for cash or cash equivalent, gain or loss on the sale is recognized, taking into consideration the amount of any recorded impairment if the property had been assessed individually. If a partial interest in an unproved property is sold, the amount received is treated as a reduction of the cost of the interest retained.

Oil and Natural Gas Sales Receivable

Oil and natural gas sales receivable principally consist of accrued oil and natural gas sales proceeds receivable and are typically collected within 35 days from the end of the month in which the related quantities are produced. We ordinarily do not require collateral for such receivables, nor do we charge interest on past due balances. We periodically review accounts receivable for collectability and reduce the carrying amount of the accounts receivable by an allowance. No such allowance was indicated at December 31, 2012 or 2011. As of December 31, 2012, our accounts receivable were primarily with several independent purchasers of our crude oil and natural gas production. At December 31, 2012, we had balances due from two customers which were greater than 10% of our accounts receivable related to crude oil and natural gas production. These two customers accounted for 63% of accounts receivable at December 31, 2012. At December 31, 2011, we had balances due from five customers which were greater than 10% of our accounts receivable related to crude oil and natural gas production. These five customers accounted for 80% of accounts receivable at December 31, 2011. In the event that one or more of these significant customers ceases doing business with us, we believe that there are potential alternative customers with whom we could establish new relationships and that those relationships will result in the replacement of one or more lost customers.

Joint Interest Billings Receivable and Oil and Natural Gas Revenues Payable

Joint interest billings receivable represent amounts receivable for lease operating expenses and other costs due from third party working interest owners in the wells that the Company operates. The receivable is recognized when the cost is incurred and the related payable and the Company's share of the cost is recorded. We often have the ability to offset amounts due against the participant's share of production from the related property.

The Company uses the reserve for bad debt method of valuing doubtful joint interest billings receivable based on historical experience, coupled with a review of the current status of existing receivables. The balance of the reserve for doubtful accounts, deducted against joint interest billings receivable to properly reflect the realizable value was approximately $174,000 and $99,000 at December 31, 2012 and 2011, respectively.

Oil and natural gas revenues payable represents amounts due to third party revenue interest owners for their share of oil and natural gas revenue collected on their behalf by the Company. The payable is recorded when the Company recognizes oil and natural gas sales and records the related oil and natural gas sales receivable.

Other Property

Other assets classified as property and equipment are primarily office furniture and equipment and vehicles, which are carried at cost. Depreciation is provided using the straight-line method over estimated useful lives ranging from three to five years. Gain or loss on retirement or sale or other disposition of assets is included in income in the period of disposition. Depreciation expense for other property and equipment was $6,000 and $3,000 for each of the years ended December 31, 2012 and 2011.

Asset Retirement Obligations

Our financial statements reflect our asset retirement obligations, consisting of future plugging and abandonment expenditures related to our oil and natural gas properties, which can be reasonably estimated. The asset retirement obligation is recorded at fair value on a discounted basis as a liability at the asset's inception, with an offsetting increase to producing properties on the consolidated balance sheets. Periodic accretion of the discount of the estimated liability is recorded as an expense in the consolidated statements of operations.

The following is a reconciliation of the Company's asset retirement obligations for the years ended December 31:

	2012			2011
Asset retirement obligation at January 1,	$	1,515,002		$	1,405,002
Accretion of discount		91,000			84,000
Liabilities incurred during the year		22,000			26,000
Liabilities settled during the year		(32,067	)		-
Asset retirement obligation at December 31,	$	1,595,935		$	1,515,002

The entire balance was classified as a non-current liability at December 31, 2012. At December 31, 2011, the portion of the balance classified as a current liability was $25,000 with the remainder of the balance classified as non-current.

Income Taxes

Income taxes are provided for the tax effects of transactions reported in the financial statements and consist of taxes currently due, if any, plus net deferred taxes related to differences between the bases of assets and liabilities for financial and income tax reporting. Deferred tax assets and liabilities represent the future tax consequences of those differences, which will either be taxable or deductible when the assets and liabilities are recovered or settled. Valuation allowances are recognized to limit recognition of deferred tax assets where appropriate. Such allowances may be reversed when circumstances provide evidence that the deferred tax assets will more likely than not be realized.

Production Taxes and Ad Valorem Taxes

Production taxes and ad valorem taxes are included in production expense. Total production and ad valorem taxes were $1,297,165 and $606,786 for the years ended December 31, 2012 and 2011, respectively.

Use of Estimates and Certain Significant Estimates

The preparation of the Company's financial statements in conformity with accounting principles generally accepted in the United States of America requires the Company's management to make estimates and assumptions that affect the amounts reported in these financial statements and accompanying notes. Actual results could differ from those estimates. Significant assumptions are required in the valuation of proved oil and natural gas reserves, which as described above may affect the amount at which oil and natural gas properties are recorded. The Company's allowance for doubtful accounts is a significant estimate and is based on management's estimates of uncollectible receivables. The asset retirement obligations require estimates of future plugging and abandonment expenditures. It is at least reasonably possible these estimates could be revised in the near term and the revisions could be material.

Our estimates of proved reserves materially impact depletion and impairment expense. If proved reserves decline, then the rate at which we record depletion expense increases, reducing net income. A decline in estimates of proved reserves may result from lower prices, evaluation of additional operating history, mechanical problems at our wells and catastrophic events such as explosions, hurricanes and floods. Lower prices also may make it uneconomical to drill wells or produce from fields with high operating

costs. In addition, a decline in proved reserves may impact our assessment of our oil and natural gas properties for impairment.

Our proved reserve estimates are a function of many assumptions, all of which could deviate materially from actual results. As such, reserve estimates may vary materially from the ultimate quantities of oil and natural gas actually produced.

Revenue Recognition

The Company uses the sales method of accounting for oil and natural gas revenues. Under this method, revenues are based on actual volumes of oil and natural gas sold to purchasers. The volumes of natural gas sold may differ from the volumes to which the Company is entitled based on its interest in the properties. Differences between volumes sold and volumes based on entitlements create natural gas imbalances. Material imbalances are reflected as adjustments to reported natural gas reserves and future cash flows. There were no material natural gas imbalances as of December 31, 2012 and 2011.

We recognize revenue when crude oil and natural gas quantities are delivered to or collected by the respective purchaser. Title to the produced quantities transfers to the purchaser at the time the purchaser receives or collects the quantities. Prices for such production are defined in sales contracts and are readily determinable based on certain publicly available indices. The purchasers of such production have historically made payment for crude oil and natural gas purchases within thirty-five days of the end of each production month. We periodically review the difference between the dates of production and the dates we collect payment for such production to ensure that accounts receivable from those purchasers are collectible.

As previously discussed, we sold our crude oil and natural gas production to several independent purchasers. During the year ended December 31, 2012, we had sales of 10% or more of our total oil and natural gas sales revenue to four customers which represented 64% of total oil and natural gas sales revenue for the year ended December 31, 2012. During the year ended December 31, 2011, we had sales of 10% or more of our total oil and natural gas sales revenue to four customers representing 61% of total oil and natural gas sales revenue for the year ended December 31, 2011.

Comprehensive Income

The Company has no elements of comprehensive income other than net income.

Share-Based Compensation

We measure and record compensation expense for all share-based payment awards to employees and directors based on estimated fair values. Additionally, compensation costs for share-based awards are recognized over the requisite grant-date service period based on the grant-date fair value. There were no outstanding share-based awards during 2012 or 2011.

Financial Instruments

The Company's financial instruments are cash, certificates of deposit, accounts receivable and payable and long-term debt. Management believes the fair values of these instruments, with the exception of the long-term debt, approximate the carrying values, due to the short-term nature of the instruments. Management believes the fair value of long-term debt also reasonably approximates its carrying value, based on expected cash flows and interest rates.