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FXEN > SEC Filings for FXEN > Form 10-Q on 9-May-2013All Recent SEC Filings

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Form 10-Q for FX ENERGY INC


Quarterly Report



The majority of our operations are in Poland, and we have devoted most of our technical talent and capital expenditures in the last several years to our operations in that country. The decision to devote most of our available capital to this area drives our operating results and the changes to our balance sheet and liquidity. Our operations in Poland, which are a combination of existing production and substantial exploration, have grown considerably. Oil and gas production, oil and gas revenues, cash flow, earnings, oil and gas reserves, and oil and gas expenditures in this area have grown significantly over the last three years.

Our U.S. operations also have an impact. Our U.S. operations are smaller than those in Poland and do not present the same level of opportunities for expansion; however, our U.S. operations are a relatively stable source of cash flow. This, too, is reflected in our operating results.

Results of Operations by Business Segment

Quarter Ended March 31, 2013, Compared to the Same Period of 2012

Exploration and Production Segment

Gas Revenues. Revenues from gas sales were approximately $8.5 million during the first quarter of 2013, compared to $6.8 million during the same quarter of 2012. Increased production and higher prices accounted for the increase in 2013 first quarter natural gas revenues.

A summary of the amount and percentage change, as compared to the respective prior-year period, for gas revenues, average gas prices, and gas production volumes for the quarters ended March 31, 2013 and 2012, is set forth in the following table:

                                          For the Quarter Ended March 31,
                                              2013               2012         Change
Gas revenues                                  $8,546,000         $6,771,000    +26%
Average price (per thousand cubic feet)            $7.18              $6.03    +19%
Production volumes (thousand cubic feet)       1,190,000          1,123,000    +6%

Daily gas production increased to 13.2 million cubic feet of natural gas per day, or MMcfd, in the first quarter of 2013, compared to 12.5 MMcfd in the first quarter of 2012, an increase of 6%. Production from our Kromolice-1, Sroda-4, and Kromolice-2, or KSK, wells increased by 256,000 thousand cubic feet of natural gas, or Mcf, over 2012 first quarter levels, as first quarter 2012 production at KSK was constrained due to a pipeline bottleneck issue. In addition, new production at our Winna Gora well combined with the KSK increase to offset production declines at our Zaniemysl well.

Our higher production was augmented by higher prices during the 2013 quarter. Three factors contributed to the increase in average prices. First, the Polish low-methane tariff, which serves as the reference price for our gas sales agreements, was 13.1% higher during the first quarter of 2013. Second, period-to-period weakness in the U.S. dollar against the Polish zloty increased our U.S. dollar-denominated gas prices. The average exchange rate during the first quarter of 2013 was 3.15 zlotys per U.S. dollar. The average exchange rate during the first quarter of 2012 was 3.23 zlotys per U.S. dollar, a change of approximately 2%. Lastly, production declines at Zaniemysl were replaced by production gains at both KSK and Winna Gora, where our average price per Mcf is approximately 20% higher than at Zaniemysl.

Oil Revenues. First quarter 2013 oil revenues declined by 22% from first quarter of 2012 oil revenues. Production levels were down 13% from quarter to quarter, due to normal production declines, while oil prices were down 10% from quarter to quarter. Our average oil price during the first quarter of 2013 was $76.46 per barrel, compared to $84.97 per barrel received during the same quarter of 2012.

A summary of the amount and percentage change, as compared to the respective prior-year period, for oil revenues, average oil prices, and oil production volumes for the quarters ended March 31, 2013 and 2012, is set forth in the following table:

                               For the Quarter Ended March 31,
                                  2013               2012          Change
Oil revenues                       $900,000           $1,152,000    -22%
Average price (per barrel)           $76.46               $84.97    -10%
Production volumes (barrels)         11,800               13,600    -13%

Lease Operating Costs. Lease operating costs were essentially unchanged from the first quarter of 2012 to 2013. Poland operating costs increased approximately 10% from quarter to quarter, with the bulk of the increase attributable to new production at Winna Gora. Conversely, operating costs and production taxes in the U.S. declined by approximately 5% from 2012 to 2013. The net effect of these changes was an increase in total operating costs of $4,000 from quarter to quarter.

Exploration Costs. Our exploration costs consist of geological and geophysical costs and the costs of exploratory dry holes. Exploration costs were $6.4 million during the first quarter of 2013, compared to $3.0 million during the same period of 2012. First quarter 2013 exploration costs included approximately $3.2 million in dry hole costs associated with our Mieczewo well in Poland, $2.5 million associated with three-dimensional, or 3-D, seismic projects at our Fences concession, and the remainder associated with two-dimensional, or 2-D, seismic and other costs at other existing Polish concessions. First quarter 2012 exploration costs included approximately $400,000 associated with 3-D seismic survey in our Fences concession, $2.1 million associated with 2-D seismic projects at our other existing Polish concessions, and approximately $460,000 in dry-hole costs associated with a Bakken test well in Montana.

DD&A Expense - Exploration and Production. DD&A expense for producing properties was $1.1 million for the first quarter of 2013, an increase of 69%, compared to $632,000 during the same period of 2012. Higher DD&A expense in 2013 was due in part to increased depreciation expense at our KSK and Winna Gora wells, reflecting higher and new production in 2013.

Accretion Expense. Accretion expense was $22,000 and $16,000 for the first quarter of 2013 and 2012, respectively. Accretion expense is related entirely to our asset retirement obligation associated with expected future plugging and abandonment costs.

Oilfield Services Segment

Oilfield Services Revenues. Oilfield services revenues were $42,000 during the first quarter of 2013, compared to $659,000 for the first quarter of 2012. During the first quarter of 2013, we performed only minimal well service work for third parties. All of the 2012 revenues were associated with drilling at our joint venture Bakken project in Montana. Revenues for this project were recorded net of any intercompany profit. We drilled no wells for third parties during the 2012 quarter. Oilfield services revenues will continue to fluctuate from period to period based on market demand, weather, the number of wells drilled, downtime for equipment repairs, the degree of emphasis on utilizing our oilfield servicing equipment on our Company-owned properties, and other factors.

Oilfield Services Costs. Oilfield services costs were $132,000 during the first quarter of 2013, compared to $639,000 during the same period of 2012. The quarter-to-quarter decrease was primarily due to decreased drilling activities associated with our joint venture Bakken project in Montana. Oilfield services costs will also continue to fluctuate period to period based on market demand, weather, the number of wells drilled, downtime for equipment repairs, the degree of emphasis on utilizing our oilfield servicing equipment on our Company-owned properties, and other factors.

DD&A Expense - Oilfield Services. DD&A expense for oilfield services was $239,000 during the first quarter of 2013, compared to $287,000 during the same period of 2012. DD&A decreased from quarter to quarter as certain assets became fully depreciated.

Nonsegmented Information

G&A Costs. G&A costs were $1.8 million during the first quarter of 2013, compared to $1.9 million during the first quarter of 2012, a decrease of $67,000. Decreased costs in 2013 were due primarily to lower consulting and travel costs.

Stock Compensation (G&A). For the three-month periods ended March 31, 2013 and 2012, we recognized $689,000 and $551,000, respectively, of stock compensation expense related to the amortization of unexercised options and restricted stock.

Interest and Other Income (Expense). Interest and other income was $52,000 during the first quarter of 2013, a decrease of $32,000, compared to $84,000 during the same period of 2012. The decrease was a reflection of lower cash balances available for investment and lower interest rates. During the first quarter of 2013, we incurred $628,000 in interest expense, which included $130,000 of amortization of previously incurred loan fees. During the first quarter of 2012, we incurred $619,000 in interest expense, which included $127,000 of amortization of previously incurred loan fees.

Foreign Exchange Gains and Losses. As discussed in note 10 to the financial statements, during the first quarter of 2013, we recorded foreign currency transaction losses of approximately $9.1 million, principally attributable to increases in the amount of Polish zlotys necessary to satisfy outstanding intercompany and other dollar-denominated loans. We recorded foreign exchange gains of $14.5 million during the same quarter of 2012, which were also principally related to our intercompany loans. Exchange-rate fluctuation from year-end 2012 to March 31, 2013, of 2% was less than the exchange-rate fluctuation from year-end 2011 to March 31, 2012, of 9%. The decrease in volatility resulted in a lower foreign exchange impact in 2013 compared to 2012.

Liquidity and Capital Resources

For much of our history, we have financed our operations principally through the sale of equity securities, bank borrowings, and agreements with industry participants that funded our share of costs in certain exploratory activities in return for an interest in our properties. However, as our gas production and prices have increased in Poland in the last several years and as higher oil prices have improved the profitability of our U.S. production, our internally generated cash flow has become a significant source of operations financing.

2013 Liquidity and Capital

Working Capital (current assets less current liabilities). Our working capital was $24.8 million as of March 31, 2013, down $5.6 million from December 31, 2012. Our current assets at March 31, 2013, included approximately $4.1 million in accrued oil and gas sales from both the United States and Poland. Our current liabilities at quarter-end included approximately $6.7 million in costs related to capital and exploration projects in Poland. Our total outstanding long-term debt at quarter-end, including the current portion, was $40 million.

Operating Activities. Net cash provided by operating activities was $4.5 million during the first three months of 2013, down 3% from the $4.7 million during the first three months of 2012. Higher exploration expenses, along with changes in accounts payable at March 31, 2013, offset higher revenues and reductions in receivables in the first quarter of the year.

Investing Activities. During the first three months of 2013, we used cash of $5.5 million in investing activities. We used $5.3 million for capital additions in Poland and $192,000 for capital additions in our office and drilling equipment. During the first three months of 2012, we used cash of $5.3 million in investing activities. We used $5.1 million for capital additions in Poland and $178,000 for capital additions in our office and drilling equipment.

Financing Activities. There were no financing transactions during the first quarter of 2013 or 2012.

Our Capital Resources and Future Expenditures

Our anticipated sources of liquidity and capital for 2013 include our working capital of $24.8 million at March 31, 2013, available credit under our expanded credit facility, and cash available from future operations.

In August 2010, we refinanced our existing credit facility by executing an expanded credit facility with The Royal Bank of Scotland Plc, ING Bank N.V., and KBC Bank NV. The expanded credit facility calls for a periodic interest rate of LIBOR plus 4.0% and has a term of five years, with semiannual borrowing base reductions of $11 million each beginning on June 30, 2013. As of March 31, 2013, we had $40 million outstanding under the facility and $15 million of available credit. At the time of this report, we are in the process of extending and expanding our credit facility. If we do not complete the new credit facility, our borrowing base will be reduced to $44 million on June 30, 2013, and we will be required to make a $7.0 million principal payment under the terms of our existing facility on December 31, 2013. The new facility is expected to have terms similar to our existing facility and is expected to be finalized prior to the scheduled borrowing base reduction on June 30, 2013.

We currently have increased cash from our operating activities to help fund our exploration and development activities in 2013. We expect that our 2013 production will be higher than our 2012 production with the addition of production at our Winna Gora-1, Lisewo-1, and Komorze-3K wells, as well as full production from our KSK wells. Production began at Winna Gora-1 in late January of 2013. Production is expected to begin at Lisewo-1 and at Komorze-3K during the second half of 2013. We currently expect to receive 86% of the published low-methane tariff, adjusted for energy content, for each of the three new wells. The amount of revenue from this increased production will depend on applicable gas sales prices and prevailing currency exchange rates.

We have an effective Securities Act universal shelf registration statement under which we may sell up to $200 million of equity or debt securities of various kinds. In June 2012, we entered into an agreement to possibly sell up to $50 million in common stock during the next two years in at-the-market transactions. Through the date of this filing, we have not sold any stock under that agreement. Assuming all $50 million of common stock covered by the at-the-market facility were sold, the remaining $150 million balance of securities available for sale under the registration statement is available for sale at any time, subject to market conditions and our ability to access the capital markets, to further finance our exploration and development plans in Poland and for other corporate purposes.

At March 31, 2013, we were in the process of drilling the Tuchola-3 well, having incurred a total cost of $3.8 million through the end of the quarter, with the total cost expected to be approximately $8 million. We have agreed with the Polish Oil and Gas Company, or PGNiG, to conduct a fracture stimulation test at the Plawce-2 well, which began during April of 2013. We were also in the process of building a pipeline and production facilities at our Lisewo and Komorze wells. We had no other firm commitments for future capital and exploration costs at March 31, 2013.

We expect our primary use of cash for 2013 will be for our exploration and development activities in Poland. Our board of directors has approved projects whose cost is expected to range from $60 million to $70 million for production facilities for existing discoveries, exploration and development wells, and 2-D and 3-D seismic data acquisition and analysis, including those items noted above. All of the approved projects may not be completed during 2013, but we do expect to start work on all of them in the next 12 months.

The actual amount of our expenditures will depend on ongoing exploration results; the pace at which PGNiG, our operating partner in the Fences project area, wishes to proceed or the extent it wishes to continue to participate with us in concessions we operate; the availability of drilling and other exploration services; and the amount of capital we obtain from the various sources discussed above. Our various sources of liquidity and capital outlined above should more than enable us to meet our capital needs in Poland and the United States for the next 12 months. We have the ability to control the timing and amount of most of our future capital and exploration costs.

We may continue to incur operating losses in future periods, and we continue to fund substantial exploration and development in Poland. We have a history of operating losses. From our inception in January 1989 through March 31, 2013, we have incurred cumulative net losses of approximately $197 million. Despite our recent and expected future increases in production and revenues, our exploration and production activities may continue to result in net losses in future years, depending on the success of our drilling activities in Poland and the United States and whether we generate sufficient revenues to cover related operating expenses.

We may also seek to obtain additional funds for future capital investments from the sale of partial property interests or arrangements such as those negotiated in prior years for our Kutno and Warsaw South project areas in which industry participants are bearing the initial exploration costs to earn an interest in the project or other arrangements, all of which may dilute the interest of our existing stockholders or our interest in the specific project financed.

We will allocate our existing capital, as well as funds we may obtain in the future, among our various projects at our discretion. We may change the allocation of capital among the categories of anticipated expenditures depending upon future events. For example, we may change the allocation of our expenditures based on the actual results and costs of future exploration, appraisal, development, production, property acquisition, and other activities. In addition, we may have to change our anticipated expenditures if costs of placing any particular discovery into production are higher, if the field is smaller, or if the commencement of production takes longer than expected.

New Accounting Pronouncements

We have reviewed all other recently issued, but not yet adopted, accounting standards in order to determine their effects, if any, on our consolidated results of operations, financial position, and cash flows. Based on that review, we believe that none of these pronouncements will have a significant effect on current or future earnings or operations.

Critical Accounting Policies

A summary of our significant accounting policies is included in Note 1 of our Consolidated Financial Statements contained in our annual report on Form 10-K for the year ended December 31, 2012. We believe the application of these accounting policies on a consistent basis enables us to provide financial statement users with useful, reliable, and timely information about our earnings results, financial condition, and cash flows.

The preparation of financial statements in accordance with GAAP requires our management to make judgments, estimates, and assumptions regarding uncertainties that affect the reported amounts presented and disclosed in the financial statements. Our management reviews these estimates and assumptions, which are based on historical experience, changes in business conditions, and other relevant factors that it believes to be reasonable under the circumstances. In any given reporting period, actual results could differ from the estimates and assumptions used in preparing our financial statements.

Critical accounting policies are those that may have a material impact on our financial statements and also require management to exercise significant judgment due to a high degree of uncertainty at the time the estimate is made. Our senior management has discussed the development and selection of our accounting policies, related accounting estimates, and the disclosures set forth below with the Audit Committee of our Board of Directors. We believe our critical accounting policies include those addressing the recoverability and useful lives of assets, the retirement obligations associated with those assets, and the estimates of oil and gas reserves.

Forward-Looking Statements

This report contains statements about the future, sometimes referred to as "forward-looking" statements. Forward-looking statements are typically identified by the use of the words "believe," "may," "could," "should," "expect," "anticipate," "estimate," "project," "propose," "plan," "intend," and similar words and expressions. We intend that the forward-looking statements will be covered by the safe harbor provisions for forward-looking statements contained in Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Statements that describe our future strategic plans, goals, or objectives are also forward-looking statements.

Readers of this report are cautioned that any forward-looking statements, including those regarding us or our management's current beliefs, expectations, anticipations, estimations, projections, proposals, plans, or intentions, are not guarantees of future performance or results of events and involve risks and uncertainties, such as the future timing and results of drilling individual wells and other exploration and development activities; future variations in well performance as compared to initial test data; future events that may result in the need for additional capital; the prices at which we may be able to sell oil or gas; fluctuations in prevailing prices for oil and gas; our ability to complete the acquisition of targeted new or expanded exploration or development prospects; uncertainties of certain terms to be determined in the future relating to our oil and gas interests, including exploitation fees, royalty rates, and other matters; future drilling and other exploration schedules and sequences for various wells and other activities; uncertainties regarding future political, economic, regulatory, fiscal, taxation, and other policies in Poland; the cost of additional capital that we may require and possible related restrictions on our future operating or financing flexibility; our future ability to attract strategic participants to share the costs of exploration, exploitation, development, and acquisition activities; and future plans and the financial and technical resources of strategic participants.

The forward-looking information is based on present circumstances and on our predictions respecting events that have not occurred, that may not occur, or that may occur with different consequences from those now assumed or anticipated. Actual events or results may differ materially from those discussed in the forward-looking statements as a result of various factors. The forward-looking statements included in this report are made only as of the date of this report. We disclaim any obligation to update any forward-looking statements whether as a result of new information, future events, or otherwise.

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