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Current RRC Stock Info

Range Resources Corporation (ticker: RRC)  is one of the leading independent oil and natural gas producers in the US. Its operations are primarily focused in the Marcellus Shale in Appalachia and liquids-rich areas of the Southwest.

On January 30, 2013, RRC announced  that its proved reserves as of December 31, 2012 increased 29% to a record high of 6.5 Tcfe. Range replaced 773% of production in 2012 from drilling (including proved performance revisions). Finding and development costs from all sources (including acreage and price and performance revisions) are expected to average $0.87 per mcfe, based on preliminary unaudited results for 2012. Drill bit development costs are expected to average $0.68 per mcfe.

For 2012, Range added 1,767 Bcfe of proved reserves through the drill bit. Positive performance revisions added 366 Bcfe despite the Company removing 67 Bcfe of proved undeveloped dry gas reserves that are no longer expected to be drilled within the next five years under current development plans as the Company continues to redirect capital to the Marcellus Shale, the Horizontal Mississippian oil play and other liquids-rich areas of the Company’s portfolio. Price revisions reduced proved reserves by 257 Bcfe. During the year, the Company sold 149 Bcfe of proved reserves. No reserves were added through purchases as the Company did not have any proved property acquisitions in 2012. Production for 2012 totaled 276 Bcfe.

Year-end 2012 proved reserves by volume were 74% natural gas, 22% natural gas liquids and 4% crude oil. Crude oil and NGL reserve volumes increased 64%, while natural gas reserve volumes increased 20%. The percentage of reserves in the proved undeveloped category declined to 47% at year-end 2012, as compared to 52% at year-end 2011. At year-end 2012, Range recorded, on average, a modest 1.2 offset Marcellus drilling locations to its proved undeveloped reserves for each of its proved developed wells in the play. As of year-end 2012, approximately 10% of Range’s Marcellus acreage was classified as proved reserves. Given the results to date of Range and other operators with over 2,000 wells drilled around Range’s acreage, Range believes that substantially all of its Marcellus acreage is highly prospective. In regard to the Utica and Upper Devonian Shales, Range has drilled successful wells in both horizons and will continue to drill additional wells and monitor industry activity. However at year-end 2012 as in 2011 and 2010, Range did not include any Utica or Upper Devonian locations as proved undeveloped reserves.

At year-end 2012, the Company recognized 307 Bcfe of incremental ethane reserves as NGL proved reserves in the Marcellus Shale associated with initial ethane deliveries under contracts commencing in 2013. The remaining Marcellus ethane reserves continue to be included as natural gas reserves until additional ethane contracts commence in 2014 and 2015. As a result, the majority of its ethane volumes are currently left in the natural gas stream and sold on an energy equivalent basis. If ethane recovery were occurring at year-end 2012 for all the ethane deliveries under currently executed contracts, the Company’s estimated proved reserves by volume would have been 7.0 Tcfe, composed of 66% natural gas, 30% NGLs and 4% crude oil. In all geographical areas other than the Marcellus, ethane is normally included in the NGL reserves under customary reporting practices.

As noted above, Range replaced 773% of production from drilling in 2012 including performance revisions. The Company’s estimate of drilling and development costs incurred during 2012 including acreage, exploration and seismic expenses is approximately $1.65 billion which is subject to year-end audit. Included in the $1.65 billion capital spending amount is approximately $190 million for acreage. Finding and development cost from all sources averaged $0.87 per mcfe including price and performance revisions. Drill bit development cost (which excludes price revisions and acreage cost) averaged $0.68 per mcfe.

The Securities and Exchange Commission (“SEC”) rules require that proved reserve calculations be based on the prompt month average prices over the preceding twelve months. For the year-end 2012 reserve evaluation, the benchmark prices were $2.76 per Mmbtu for natural gas and $95.05 per barrel for crude oil (Cushing), representing the simple average of the prices for the first day for each month of 2012. Comparative prices for year-end 2011 were $4.12 per Mmbtu for natural gas and $95.61 per barrel for crude oil (Cushing). Based on these prices adjusted for energy content, quality and basis differentials ($2.75 per Mmbtu, $32.23 per barrel of natural gas liquids and $86.91 per barrel of crude oil, respectively), the pre-tax discounted (10%) present value (“PV10”) of the Company’s proved reserves was $4.0 billion for year-end 2012 compared to $6.1 billion at year-end 2011. The Company’s PV10 value of its proved reserves includes estimated future development costs to develop the proved undeveloped reserves of $3.5 billion. Using the 10-year future strip benchmark prices as of December 31, 2012, the Company’s PV10 value would have been $8.2 billion. The 10-year future strip benchmark prices were $4.84 per Mmbtu and $87.90 per barrel. The comparative prior year PV10 value using 10-year future strip benchmark prices as of December 31, 2011 of $4.90 per Mmbtu and $92.66 per barrel, was $7.4 billion.

SUMMARY OF CHANGES IN PROVED RESERVES
(in Bcfe)
Balance at December 31, 2011 5,054
Extensions, discoveries and additions 1,767
Purchases
Performance revisions 366
Price revisions (257 )
Sales (149 )
Production (276 )
Balance at December 31, 2012 6,505

Commenting, Jeff Ventura, Range’s President and CEO, said, “Our 29% increase in proved reserves, 773% drill bit replacement and $0.87 all-in finding cost are outstanding results. Importantly, we achieved double-digit per share, debt-adjusted production and reserve growth for the seventh consecutive year. These results are a reflection of our large inventory of low cost, high return projects. Given the commodity price environment in 2012, and to a greater extent in 2013, we are focusing our capital on our liquids-rich plays. The 64% increase in crude oil and NGL reserves versus the 20% rise in natural gas reserves is a reflection of the solid execution of our capital program. Again for 2013, we expect our growth in liquid reserves will materially outpace the growth in our natural gas reserves. The fact that only 10% of our Marcellus acreage is classified as proved reserves along with our growing oil production from the Horizontal Mississippian play, demonstrates that Range is very well positioned to continue to achieve double-digit production and reserve growth per share at low cost for many years to come.”

Disclosure Statements:

The information in this release is unaudited and subject to revision. Audited and final results will be provided in our Annual Report on Form 10-K for the year ended December 31, 2012 currently planned to be filed with Securities and Exchange Commission by the end of February 2013.

Range has disclosed two primary metrics in this release to measure our ability to establish a long-term trend of adding reserves at a reasonable cost – a reserve replacement ratio and finding and development cost per unit. The reserve replacement ratio is an indicator of our ability to replace annual production volumes and grow our reserves. It is important to economically find and develop new reserves that will offset produced volumes and provide for future production given the inherent decline of hydrocarbon reserves as they are produced. We believe the ability to develop a competitive advantage over other natural gas and oil companies is dependent on adding reserves in our core areas at lower costs than our competition. The reserve replacement ratio is calculated by dividing production for the year into the total of proved extensions, discoveries and additions and proved reserves added by performance as shown in the table.

Finding and development cost per unit is a non-GAAP metric used in the exploration and production industry by companies, investors and analysts. The calculations presented by the Company are based on estimated and unaudited costs incurred excluding asset retirement obligations and divided by proved reserve additions (extensions, discoveries and additions shown in the table) adjusted for the changes in proved reserves for acreage, acquisitions, performance revisions and/or price revisions as stated in each instance in the release. This calculation does not include the future development costs required for the development of proved undeveloped reserves.

The reserve replacement ratio and finding and development cost per unit are statistical indicators that have limitations, including their predictive and comparative value. As an annual measure, the reserve replacement ratio can be limited because it may vary widely based on the extent and timing of new discoveries and the varying effects of changes in prices and well performance. In addition, since the reserve replacement ratio and finding and development cost per unit do not consider the cost or timing of future production of new reserves, such measures may not be an adequate measure of value creation. These reserves metrics may not be comparable to similarly titled measurements used by other companies.

Year-end pre-tax discounted present value may be considered a non-GAAP financial measure as defined by the SEC. We believe that the presentation of pre-tax discounted present value is relevant and useful to our investors because it presents the discounted future net cash flows attributable to our proved reserves prior to taking into account corporate future income taxes and our current tax structure. We further believe investors and creditors use pre-tax discounted present value as a basis for comparison of the relative size and value of our reserves as compared with other companies. Range’s pre-tax discounted present value as of December 31, 2012 may be reconciled to its standardized measure of discounted future net cash flows as of December 31, 2012 by reducing Range’s pre-tax discounted present value by the discounted future income taxes associated with such reserves. This reconciliation will be included in the Company’s Form 10-K.

Except for historical information, statements made in this release, including those relating to finding and development costs in 2012 that are still subject to audit, expected acreage to be reclassified to proved developed, expected timing and volumes of ethane reserves recognized as proved reserves, expected future growth in liquid reserves, expected future growth of production and reserves per share, expected rates of return and future expectation of costs are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. These statements are based on assumptions and estimates that management believes are reasonable based on currently available information; however, management’s assumptions and Range’s future performance are subject to a wide range of business risks and uncertainties and there is no assurance that these goals and projections can or will be met. Any number of factors could cause actual results to differ materially from those in the forward-looking statements, including, but not limited to, the volatility of oil and gas prices, the results of our hedging transactions, the costs and results of drilling and operations, the timing of production, mechanical and other inherent risks associated with oil and gas production, weather, the availability of drilling equipment, changes in interest rates, litigation, uncertainties about reserve estimates, environmental risks and regulatory changes. Range undertakes no obligation to publicly update or revise any forward-looking statements. Further information on risks and uncertainties is available in Range’s filings with the Securities and Exchange Commission (“SEC”), which are incorporated by reference.

The SEC permits oil and gas companies, in filings made with the SEC, to disclose proved reserves, which are estimates that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions as well as the option to disclose probable and possible reserves. Range has elected not to disclose the Company’s probable and possible reserves in its filings with the SEC. Range uses certain broader terms such as “resource potential,” or “unproved resource potential” or “upside” or other descriptions of volumes of resources potentially recoverable through additional drilling or recovery techniques that may include probable and possible reserves as defined by the SEC’s guidelines. Range has not attempted to distinguish probable and possible reserves from these broader classifications. The SEC’s rules prohibit us from including in filings with the SEC these broader classifications of reserves. These estimates are by their nature more speculative than estimates of proved, probable and possible reserves and accordingly are subject to substantially greater risk of being actually realized. Unproved resource potential refers to Range’s internal estimates of hydrocarbon quantities that may be potentially discovered through exploratory drilling or recovered with additional drilling or recovery techniques and have not been reviewed by independent engineers. Unproved resource potential does not constitute reserves within the meaning of the Society of Petroleum Engineer’s Petroleum Resource Management System and does not include proved reserves. Area wide unproven, unrisked resource potential has not been fully risked by Range’s management. Actual quantities that may be ultimately recovered from Range’s interests will differ substantially. Factors affecting ultimate recovery include the scope of Range’s drilling program, which will be directly affected by the availability of capital, drilling and production costs, commodity prices, availability of drilling services and equipment, drilling results, lease expirations, transportation constraints, regulatory approvals, field spacing rules, recoveries of gas in place, length of horizontal laterals, actual drilling results, including geological and mechanical factors affecting recovery rates and other factors. Estimates of resource potential may change significantly as development of our resource plays provides additional data. Investors are urged to consider closely the disclosure in our most recent Annual Report on Form 10-K, available from our website at www.rangeresources.com or by written request to 100 Throckmorton Street, Suite 1200, Fort Worth, Texas 76102. You can also obtain this Form 10-K by calling the SEC at 1-800-SEC-0330.

Contact:
Range Resources Corporation
Investor Contacts:
Rodney Waller, 817-869-4258
Senior Vice President
or
David Amend, 817-869-4266
Investor Relations Manager
or
Laith Sando, 817-869-4267
Senior Financial Analyst
or
Michael Freeman, 817-869-4264
Financial Analyst
or
Media Contact:
Matt Pitzarella, 724-873-3224
Director of Corporate Communications

Oil & Gas 360® compiled a few paragraphs from research analysts who wrote on Range Resources following the announcement.  OAG360 suggests that you contact the analyst and/or salesperson to receive a complete copy of the report. Please read the important disclosures at the end of this note.

*UBS Investment Research (1.30.13)

RRC increases proved reserves 29% at attractive cost of $0.87/Mcfe. RRC increased proved reserves by 29% to 6.5 Tcfe, modestly exceeding UBSe of 26% growth. Results included 257 Bcfe of negative price-related revisions, offset by 366 Bcfe of positive performance revisions. Including revisions, reserve replacement costs were $0.87/Mcfe, vs UBSe of $0.95/Mcfe and in line with its 3- yr avg of $0.83/Mcfe. YE12 proved undeveloped reserves increased 16% YoY to ~3.1 Tcfe and now account for 47% of companywide reserves, down from 52% at year end 2011. Natgas now represents 74% of overall reserves, down from 79%.

Reserve growth understated; excluded full ethane recovery, Utica, Upper Devonian. RRC booked just 1.2 Marcellus PUD locations for each developed well. RRC continues to book the majority of its ethane reserves in the dry gas stream until facilities to extract and sell ethane are in place in 2013. Had ethane been included as NGLs, reserves would have been an even higher 7.0 Tcfe. Also, despite favorable well results in the Utica and Upper Devonian shales, RRC did not book any proved reserves from these zones.

Modest increase to 3P resource; expect little change to NAV. RRC increased its 3P resource from 47-66 Tcfe to 48-68 Tcfe. This is broken down between 35-46 Tcf of gas and 2.3-3.5 BBbls of liquids with 54% attributable to the Marcellus. Given little change to the 3P resource, we expect to make very minor changes to our NAV when more detailed disclosure is provide din the 10-K.

Valuation: premium to peers on EV/EBITDX and price/NAV. Our $68 target assumes 0.9x NAV under current NYMEX strip prices.

*Baird Equity Research (1.30.13)

RRC proved reserves +29% Y/Y, unproved reserves to 48-68 Tcfe (Peng). Range announced this morning that its 2012 year-end proved reserves were 6.5 Tcfe (+29% Y/Y, 74% gas, 47% PUD), ahead of our estimate of 6.23 Tcfe. Drillbit replacement (including revisions) was 773% for the year; also note that natural gas reserves increased +20% Y/Y while oil/NGL reserves increased +64% Y/Y. Drillbit F&D cost was $0.68/mcfe and all-in F&D cost was $0.87/mcfe, an improvement over last year’s costs of $0.77/mcfe and $0.94/mcfe, respectively.

Also of interest was the booking of +307 Bcfe of incremental ethane due to sales contracts coming online in 2013 (excluding contracts commencing in 2014/2015); per company estimates proved reserves would have been 7.0 Tcfe if all ethane sales contracts were in place. Extensions, discoveries, and additions were +1,767 Bcfe, with other contributors to delta vs. last year including performance revisions (+366 Bcfe), price revisions (-257 Bcfe), sales (-149 Bcfe) and production (-276 Bcfe).

Updated pre-tax PV10 was $4.0B based on $2.76 gas and 95.05 oil benchmark prices. Company notes PV10 would have been $8.2B based on 10-year future strips of $4.84 gas and $87.90 oil. Also of note, only 10% of RRC’s Marcellus acreage is classified as proved reserves demonstrating tremendous resource upside.

Range also updated its unproved resource potential estimate to 48-68 Tcfe (previously 47-66 Tcfe), assuming full ethane recovery and of which 54% is within the Marcellus Shale. Despite having drilled successful wells in the Utica and Upper Devonian, RRC has not booked PUDs in these two plays or any unproved resource potential in the Utica. Net/net, we view this release positively due to better-than-expected drillbit replacement ratio and F&D costs.

*Raymond James Equity Research (1.30.13)

Range (RRC/$68.03/Market Perform) announces 29% increase in proved reserves. Range’s year-end 2012 proved reserves improved to 6.5 Tcfe (74% natural gas, 22% NGL, 4% crude), with proved undeveloped reserves (PUDs) booked decreasing to 47% from 52%. The reserves imply a 773% replacement ratio, and the company expects finding and development (F&D) costs to average $0.87/Mcfe. The unproved reserve potential as of year-end 2012 was also announced, increasing 3% (35-65 Tcf of natural gas and 2.3-3.5 billion barrels of natural gas liquids (NGLs) and crude oil.) Bottom line: the release was relatively in line with prior years, but we believe the stock should react positively today after strong bookings relative to last year, as well as the continued shift to liquids drilling, which Range indicated with successful Upper Devonian and Utica wells.

*Bank of America Merrill Lynch (1.30.13)

Reserves grow 29%; drill bit replacement 773%, PO to $80

Range reported this morning 29% growth in proved reserves to 6.5 Tcfe in 2012 and replaced 773% of production from drilling in the year. Solid reserves growth is a direct reflection of strong production in the liquids rich Marcellus. Crude oil and NGL as a percentage of total reserves increased to 26% from 21% while natural gas dropped from 79% to 74%. The percentage of PUD reserves fell slightly, down 5% to 47%. Reserve revisions of 366 Bcfe more than offset 67 Bcfe of undeveloped dry gas reserves removed under the five year rule where the resource will not be drilled in next five years alongside negative price revisions of 257 Bcfe. The company plans on continuing to redirect capital towards liquids rich regions of the Marcellus and Mississippian plays. We are increasing our PO to $80 from $77 to reflect the higher proved reserves value.

Liquids rich Marcellus boosts reserves

Range recognized 307 Bcfe of incremental ethane reserves as NGL proved reserves in its yearly estimates. However, the majority of ethane is still left in the natural gas stream until additional contracts start in 2014. Notably, only 10% of Range’s Marcellus acreage is currently accounted in the proved reserves calculation which still does not include any Utica or Upper Devonian locations and in our view could significantly boost the reserves value further.

Unproved resource potential increases to 48-68 Tcfe

RRC also announced that its estimated unrisked unproved reserve potential increased by 1.5 Tcfe to 48-67 Tcfe assuming full ethane extraction. The unproved reserve has 70% gas and approx 54% of the value is attributable to the Marcellus. Overall a solid reserve report underpinning our view that an increased focus on liquids with an acceleration of drilling in the sweet spot of the Mississippian Lime can drive one of the fastest contractions in forward multiples in the sector. RRC remains preferred stock on a more constructive outlook for natural gas. Buy.

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Important disclosures: The information provided herein is believed to be reliable; however, EnerCom, Inc. makes no representation or warranty as to its completeness or accuracy. EnerCom’s conclusions are based upon information gathered from sources deemed to be reliable. This note is not intended as an offer or solicitation for the purchase or sale of any security or financial instrument of any company mentioned in this note. This note was prepared for general circulation and does not provide investment recommendations specific to individual investors. All readers of the note must make their own investment decisions based upon their specific investment objectives and financial situation utilizing their own financial advisors as they deem necessary. Investors should consider a company’s entire financial and operational structure in making any investment decisions. Past performance of any company discussed in this note should not be taken as an indication or guarantee of future results. EnerCom is a multi-disciplined management consulting services firm that regularly intends to seek business, or currently may be undertaking business, with companies covered on Oil & Gas 360®, and thereby seeks to receive compensation from these companies for its services. In addition, EnerCom, or its principals or employees, may have an economic interest in any of these companies. As a result, readers of EnerCom’s Oil & Gas 360® should be aware that the firm may have a conflict of interest that could affect the objectivity of this note. EnerCom, or its principals or employees, may have an economic interest in any of the companies covered in this report or on Oil & Gas 360®. As a result, readers of EnerCom’s reports or Oil & Gas 360® should be aware that the firm may have a conflict of interest that could affect the objectivity of this report.