Energen Updates 2013 Outlook

Energen Updates 2013 Outlook

$900 MM E&P Capital Budget Targets Permian Drilling

BIRMINGHAM, Ala.--(BUSINESS WIRE)-- Energen Corporation (NYS: EGN) affirmed today that its 2013 consolidated capital budget of $975 million will focus primarily on the exploration and development of its liquids-rich assets in the Permian Basin of west Texas.


Energen's oil and gas exploration and production subsidiary, Energen Resources Corporation, plans to invest approximately $900 million in 2013, including some $745 million to continue developing the company's vertical Wolfberry play in the Midland Basin, the horizontal 3rd Bone Spring sand in the Delaware Basin, and its conventional and waterflood properties in the Central Basin Platform.

Another $130 million will be deployed largely to test the horizontal Wolfcamp and/or Cline potential in the Midland Basin and the horizontal Wolfcamp potential in the Delaware Basin. Energen Resources also expects to drill several wells in the Delaware Basin to test the vertical Wolfbone play.

In response to continued low natural gas prices, Energen does not plan to invest drilling capital in any of its dry gas basins. The company will, however, invest approximately $25 million largely for pay-adds and facilities in the San Juan Basin. Energen's utility operations will invest approximately $75 million in 2013 for normal system needs.

Production Guidance Revised

Energen Resources expects current infrastructure-related issues in the Permian Basin to negatively affect production in the fourth quarter of 2012 and potentially impact production in the first half of 2013, as well. Greater-than-expected ethane rejection, higher-than-anticipated line pressures, and completion delays are having a negative impact on production in the Midland Basin, while oil inventories at the well-head primarily in the Delaware Basin are growing in response to transportation infrastructure issues.

As a result, Energen has lowered its estimated 2012 and 2013 production by 400,000 barrels of oil equivalents (BOE) in each period to 24.1 million and 26.1 million BOE, respectively. Total oil and natural gas liquids (NGL) production in 2013 is estimated to increase a solid 23 percent and comprise more than half of total production.

2013 Capital, Drilling, and Production Summary

2013e Capital

2013e Wells

2013e

Production

($MM)

Gross (Net)

Rig Count

2013e

2012e

Midland Basin

$

465

185

(173)

10-11

5.6

3.6

Wolfberry

$

420

179

(167)

9-10

Wolfcamp/Cline

$

45

6

(6)

1

Delaware Basin

$

325

44

(38)

6

4.6

2.9

3rd Bone Spring

$

240

32

(28)

4

Wolfcamp/Wolfbone

$

85

12

(10)

2

Other Permian*

$

85

110

(88)

1-2

4.5

4.9

San Juan Basin/Other

$

25

0

0

11.4

12.7

TOTAL

$

900

339

(299)

17-19

26.1

24.1

* Includes 5 gross (4 net) injector wells

Production (MMBOE)

Commodity

2013e

2012e

Change

Oil

10.6

8.8

20 %

NGL

3.4

2.6

31 %

Natural Gas

12.1

12.7

(5) %

Total

26.1

24.1

8 %

2013 Financial Guidance

Energen's guidance range for 2013 consolidated after-tax cash flows is now $917-$946 million. Energen Resources' after-tax cash flows are estimated to be $822-$851 million, and Alagasco's utility operations are expected to generate after-tax cash flows of approximately $95 million. Net income in 2013 is estimated to be $219-$248 million, or $3.03-$3.43 per diluted share, and includes $22.2 million, or 31 cents per diluted share, of potential dry hole expense. Guidance does not include non-cash, mark-to-market gains or losses. [See "Non-GAAP Financial Measures" for more information and reconciliation.]

Energen Resources' estimated exploration and production expenses per BOE in 2013 are:

Lease Operating expense

Base, marketing, and transportation

$

10.25

Production taxes

$

2.48

DD&A expense

$

18.46

General & Administrative expense, net

$

3.57

Interest expense

$

2.27

Approximately 70 percent of the company's total estimated production in 2013 is hedged, including 84 percent of estimated oil production, 31 percent of estimated NGL production, and 69 percent of estimated natural gas. Assumed prices applicable to Energen Resources unhedged volumes are $90.00 per barrel of oil, $0.89 per gallon of NGL, and $3.50 per Mcf of natural gas.

Hedges also are in place that limit the company's exposure to the Midland to Cushing differential to only about 40 percent of its estimated oil production in 2013. Energen Resources has hedged the WTS Midland to WTI Cushing (sour oil) differential for 3.6 million barrels of oil production at an average price of $3.03 per barrel and the WTI Midland to WTI Cushing differential for 2.8 million barrels at an average price of $1.01 per barrel. Energen's 2013 guidance includes assumed prices applicable to Energen Resources' unhedged oil basis differentials; on an annualized basis, these are $3.35 per barrel (sour) and $2.90 per barrel (WTI Midland to WTI Cushing). Energen estimates that 64 percent of its oil production in 2013 will be sweet.

The company's current hedge position for 2013 is as follows:

Commodity

Hedge Volumes

Estimated Production

Hedge %

NYMEX Price

Oil

8.9 MMBO

10.6 MMBO

84 %

$ 90.95 per barrel

NGL

44.5 MMgal

143.4 MMgal

31 %

$ 1.02 per gallon

Natural Gas

50.0 Bcf

72.7 Bcf

69 %

$ 4.64 per Mcf*

*Basin -specific contract prices for natural gas have been converted for comparability purposes to a NYMEX-equivalent price by adding to them Energen Resources' assumed San Juan and Permian basis differentials of $0.15 per Mcf.

Average realized oil and gas prices for Energen Resources' production associated with NYMEX contracts as well as for unhedged production will reflect the impact of basis differentials; and average realized NGL prices will be net of transportation and fractionation fees. The company also has basin-specific natural gas contracts whereby Energen Resources will receive the contracted hedge price.

Gains and losses from the change in fair value of derivative instruments that do not qualify for cash flow hedge accounting are reported in operating revenues each applicable reporting period and, therefore, can cause non-cash earnings volatility.

Sensitivity of 2013e Cash Flows and Earnings to Changes in Commodity Prices

Changes in commodity prices for the remainder of the year are estimated to have the following impact on Energen's 2013 cash flows:

  • Every $1.00 change in the average NYMEX price of oil from $90 per barrel represents an estimated net impact of $750,000, or 1.0 cent per diluted share.

  • Every 1-cent change in the average price of liquids from $0.89 per gallon represents an estimated net impact of approximately $760,000, or 1.0 cent per diluted share.

  • Every 10-cent change in the average NYMEX price of gas from $3.50 represents an estimated net impact of $1.0 million, or 1.4 cents per diluted share.

Price-related events such as substantial basis differential changes could cause earnings sensitivities to be materially different from those outlined above.

Alabama Gas Corporation (Alagasco), the company's utility subsidiary, has the opportunity to earn a return on average equity that is estimated to be approximately $375-$380 million in 2013.

2012e Guidance

Energen's guidance range for 2012 consolidated after-tax cash flows is a revised $797-$804 million. Energen Resources' after-tax cash flows are estimated to be $692-$699 million. Net income in 2012 is estimated to be $228-$235 million, or $3.15-$3.25 per diluted share, and includes an estimated $8.7 million, or 12 cents per diluted share, of potential dry hole expense. This guidance does not include non-cash mark-to-market gains or losses nor the non-cash write-down of natural gas properties incurred in the first quarter of 2012. [See "Non-GAAP Financial Measures" for more information and reconciliation.]

Energen Maintains Strong Hedge Positions through 2014

Energen Resources has hedges in place through 2014 to help protect its future cash flows from commodity price volatility.

Energen Resources' 2014 hedges are as follows:

Commodity

Hedge Volumes

NYMEX Price

Oil

9.8 MMBO

$ 92.64 per barrel

Natural Gas

46.1 Bcf

$ 4.61 per Mcf*

*Basin-specific contract prices for natural gas have been converted for comparability purposes to a NYMEX-equivalent price by adding to them Energen Resources' assumed San Juan and Permian basis differentials of $0.16 per Mcf and $0.13, respectively.

Average realized oil and gas prices for Energen Resources' production associated with NYMEX contracts as well as for unhedged production will reflect the impact of basis differentials; and average realized NGL prices will be net of transportation and fractionation fees. The company has basin-specific natural gas contracts whereby Energen Resources will receive the contracted hedge price.

Gains and losses from the change in fair value of derivative instruments that do not qualify for cash flow hedge accounting are reported in operating revenues each applicable reporting period and, therefore, can cause non-cash earnings volatility.

Energen Corporation is an oil and gas exploration and production company with headquarters in Birmingham, Alabama. Through Energen Resources Corporation, the company has approximately 950 million barrels of oil-equivalent proved, probable, and possible reserves. These all-domestic reserves are located mainly in the Permian and San Juan basins. For more information, go tohttp://www.energen.com.

FORWARD LOOKING STATEMENT: This release contains statements expressing expectations of future plans, objectives and performance that constitute forward-looking statements made pursuant to the Safe Harbor provision of the Private Securities Litigation Reform Act of 1995. Except as otherwise disclosed, the Company's forward-looking statements do not reflect the impact of possible or pending acquisitions, divestitures or restructurings. We undertake no obligation to correct or update any forward-looking statements, whether as a result of new information, future events or otherwise. All statements based on future expectations rather than on historical facts are forward-looking statements that are dependent on certain events, risks and uncertainties that could cause actual results to differ materially from those anticipated. In addition, the Company cannot guarantee the absence of errors in input data, calculations and formulas used in its estimates, assumptions and forecasts. A more complete discussion of risks and uncertainties that could affect future results of Energen and its subsidiaries is included in the Company's periodic reports filed with the Securities and Exchange Commission.

Non-GAAP Financial Measures

The United States Securities and Exchange Commission requires public companies, such as Energen Corporation (the Company), to reconcile Non-GAAP (GAAP refers to generally accepted accounting principles) financial measures to related GAAP measures. After-tax Cash Flows is a Non-GAAP financial measure. Energen believes after-tax cash flows are relevant because they are a measure of cash available to fund the Company's capital expenditures, dividends, debt reduction, and other investments.

Reconciliation To GAAP Information

Years Ended 12/31

($ in millions)

2010 Actual

2011 Actual

2012 Estimate (e)

2013 Estimate (e)

Consolidated Net Income (Before asset impairment)

315

260

228

235

219

248

Asset impairment

(24

)

-

(14

)

(14

)

-

-

Consolidated Net Income (GAAP)

291

260

214

221

219

248

Depreciation, depletion and amortization (Including asset impairment)

248

284

448

448

530

530

Deferred income taxes, net

134

129

107

107

110

110

Exploratory expense

64

11

24

24

35

35

Other

3

53

4

4

23

23

After-tax Cash Flows (Non-GAAP)

740

737

797

804

917

946

Changes in assets and liabilities and other adjustments

(69

)

25

8

8

-

-

Net Cash Provided by Operating Activities (GAAP)

671

762

805

812

917

946

Reconciliation To GAAP Information

Years Ended 12/31

($ in millions)

2010 Actual

2011 Actual

2012 Estimate (e)

2013 Estimate (e)

Net Cash Provided by Operating Activities (GAAP)

671

762

805

812

917

946

Changes in assets and liabilities and other adjustments

69

(25

)