DEFA14A

 

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

 

 

SCHEDULE 14A

Proxy Statement Pursuant to Section 14(a) of the

Securities Exchange Act of 1934

(Amendment No.      )

 

 

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Whiting Petroleum Corporation

(Name of Registrant as Specified In Its Charter)

 

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

 

FORM 8-K

 

 

CURRENT REPORT

Pursuant to Section 13 or 15(d) of

the Securities Exchange Act of 1934

 

 

Date of Report (Date of earliest event reported): July 30, 2014

 

 

Whiting Petroleum Corporation

(Exact name of registrant as specified in its charter)

 

 

 

Delaware   1-31899   20-0098515
(State or other jurisdiction
of incorporation)
 

(Commission

File Number)

 

(IRS Employer

Identification No.)

1700 Broadway, Suite 2300, Denver, Colorado 80290-2300

(Address of principal executive offices, including ZIP code)

(303) 837-1661

(Registrant’s telephone number, including area code)

 

 

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

 

¨ Written communications pursuant to Rule 425 under the Securities Act (17 C.F.R. §230.425)

 

¨ Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 C.F.R. §240.14a-12)

 

¨ Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 C.F.R. §240.14d-2(b))

 

¨ Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 C.F.R. §240.13e-4(c))

 

 

 


Item 2.02. Results of Operations and Financial Condition.

On July 30, 2014, Whiting Petroleum Corporation issued a press release announcing its financial and operating results for the second quarter ended June 30, 2014 and providing certain guidance for the third quarter of 2014 and full-year 2014. A copy of such press release is furnished as Exhibit 99 and is incorporated by reference herein.

 

Item 9.01. Financial Statements and Exhibits.

 

  (a) Financial Statements of Businesses Acquired. Not applicable.

 

  (b) Pro Forma Financial Information. Not applicable.

 

  (c) Shell Company Transactions. Not applicable.

 

  (d) Exhibits:

 

  (99) Press Release of Whiting Petroleum Corporation, dated July 30, 2014.

 

-2-


SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

 

      WHITING PETROLEUM CORPORATION
Date: July 30, 2014     By:   /s/ James J. Volker
        James J. Volker
        Chairman, President and Chief Executive Officer

 

-3-


WHITING PETROLEUM CORPORATION

FORM 8-K

EXHIBIT INDEX

 

Exhibit
Number

  

Description

(99)    Press Release of Whiting Petroleum Corporation, dated July 30, 2014.

 

-4-


Exhibit 99

 

LOGO

Company contact:

  

John B. Kelso, Director of Investor Relations

  

303.837.1661 or john.kelso@whiting.com

Whiting Petroleum Corporation Announces

Second Quarter 2014 Financial and Operating Results

Record Production Reaches 109,760 BOE/d in Q2 2014, Up 9.7% Over Q1 2014,

Exceeds High End of Guidance

Record Bakken/Three Forks Production of 80,195 BOE/d in Q2 2014,

Up 33% Over Q2 2013

Redtail Niobrara Production of 7,235 BOE/d in Q2 2014,

Up 59% Over Q1 2014

Tarpon Well Completed in 2nd Bench of Three Forks Flowing 6,071 BOE/d

Raising Mid-Point of 2014 Production Guidance to 20% Over 2013

Q2 2014 Net Income Available to Common Shareholders of $151.4 Million

or $1.26 per Diluted Share and Adjusted Net

Income of $167.9 Million or $1.40 per Diluted Share

Q2 2014 Discretionary Cash Flow Totals a Record $556.2 Million

DENVER – July 30, 2014 – Whiting Petroleum Corporation’s (NYSE: WLL) production in the second quarter of 2014 totaled a record 10.0 million barrels of oil equivalent (MMBOE), of which 88% was crude oil/natural gas liquids (NGLs). The production total exceeded the high end of our guidance and equates to an average production rate of 109,760 barrels of oil equivalent per day (BOE/d), which represents a sequential increase of 9.7% over the first quarter 2014 average of 100,065 BOE/d. With our record production, we generated record discretionary cash flow of $556.2 million for the quarter.

James J. Volker, Whiting’s Chairman and CEO, commented, “Our double-play in the Bakken and Niobrara continued in the second quarter with record production and cash flow. We believe we have plenty of running room in the Williston Basin, particularly in light of our new completion techniques and downspacing programs. Our net production from the Bakken/Three Forks in the second quarter reached a record 80,195 BOE/d, representing a 33% increase over the second quarter of 2013. In the Niobrara, our net production of 7,235 BOE/d in the second quarter represented a sequential 59% increase over the first quarter of 2014.”


Mr. Volker added, “Based on our mid-year reserve estimates, the EURs associated with our well completions that used cemented liners and plug-and-perf technology were approximately 23% higher than wells completed with uncemented liners and sliding sleeve completion technology. We believe there could be additional upside from the use of coiled tubing and slickwater frac technologies. Our first slickwater frac, the Sundheim 21-27-1H, achieved a first 120-day production rate that was 44% greater than the offsetting well, which was completed using an uncemented liner and sliding sleeve technology. We plan to utilize more coiled tubing fracs and slickwater fracs in the third quarter of 2014.”

Operating and Financial Results

The following table summarizes the second quarter operating and financial results for 2014 and 2013:

 

     Three Months Ended
June 30,
        
     2014      2013      Change  

Production (MBOE/d) (1)

     109.76         93.38         +18

Discretionary Cash Flow-MM (2)

   $ 556.2       $ 440.9         +26

Realized Price ($/BOE)

   $ 82.16       $ 75.88         +8

Total Revenues-MM

   $ 835.6       $ 663.6         +26

Net Income Available to Common Shareholders-MM (3)

   $ 151.4       $ 134.7         +12

Per Basic Share

   $ 1.27       $ 1.14         +11

Per Diluted Share

   $ 1.26       $ 1.14         +11

Adjusted Net Income Available to Common Shareholders-MM (4)

   $ 167.9       $ 121.3         +38

Per Basic Share

   $ 1.41       $ 1.03         +37

Per Diluted Share

   $ 1.40       $ 1.02         +37

 

(1)  Includes production of 7.56 MBOE/d for the three months ended June 30, 2013 attributable to the Postle field, which was sold on July 15, 2013.
(2)  A reconciliation of discretionary cash flow to net cash provided by operating activities is included later in this news release.
(3)  For the three months ended June 30, 2014, net income available to common shareholders included $21.0 million of pre-tax, non-cash derivative losses or $0.11 per basic and diluted share after tax. For the three months ended June 30, 2013, net income available to common shareholders included $36.8 million of pre-tax, non-cash derivative gains or $0.20 per basic share and $0.19 per diluted share after tax.
(4)  A reconciliation of adjusted net income available to common shareholders to net income available to common shareholders is included later in this news release.

 

2


The following table summarizes the first six months operating and financial results for 2014 and 2013:

 

     Six Months Ended
June 30,
        
     2014      2013      Change  

Production (MBOE/d) (1)

     104.94         91.27         +15

Discretionary Cash Flow-MM (2)

   $ 1,038.1       $ 841.9         +23

Realized Price ($/BOE)

   $ 81.14       $ 75.34         +8

Total Revenues-MM

   $ 1,575.9       $ 1,276.9         +23

Net Income Available to Common Shareholders-MM (3)

   $ 260.5       $ 220.7         +18

Per Basic Share

   $ 2.19       $ 1.87         +17

Per Diluted Share

   $ 2.17       $ 1.86         +17

Adjusted Net Income Available to Common Shareholders-MM (4)

   $ 294.0       $ 233.0         +26

Per Basic Share

   $ 2.47       $ 1.98         +25

Per Diluted Share

   $ 2.45       $ 1.96         +25

 

(1)  Includes production of 7.62 MBOE/d for the six months ended June 30, 2013 attributable to the Postle field, which was sold on July 15, 2013.
(2)  A reconciliation of discretionary cash flow to net cash provided by operating activities is included later in this news release.
(3)  For the six months ended June 30, 2014, net income available to common shareholders included $44.7 million of pre-tax, non-cash derivative losses or $0.24 per basic share and $0.23 per diluted share after tax. For the six months ended June 30, 2013, net income available to common shareholders included $10.6 million of pre-tax, non-cash derivative gains or $0.06 per basic and diluted share after tax.
(4)  A reconciliation of adjusted net income available to common shareholders to net income available to common shareholders is included later in this news release.

Capital Budget / Production Guidance

Due to better than expected well results and a higher level of non-operated drilling activity, we are raising our 2014 production guidance and capital budget. We are increasing our capital budget to $2.8 billion from $2.7 billion primarily to reflect the increase in non-operated drilling activity. We are also making a corresponding increase in our 2014 production guidance to a mid-point of 20% over 2013, up from a mid-point of 18% over 2013.

Operational Highlights

Core Development Areas

Williston Basin Development

We hold a total of 1,059,957 gross (674,162 net) acres in the Williston Basin in North Dakota and Montana. In the second quarter of 2014, production from the Bakken/Three Forks averaged a record 80,195 BOE/d, an increase of 33% over the 60,455 BOE/d in the second quarter of 2013. The Bakken/Three Forks represented 73% of Whiting’s total second quarter production.

Cemented Liner Completions. Our cemented liner completion method has produced significant increases in well productivity. Based on our mid-year reserve estimates, we believe the EURs associated with our well completions that used cemented liners and plug-and-perf technology were approximately 23% higher than wells completed with uncemented liners and sliding sleeve completion technology.

 

3


Recent results using cemented liner completions in our Hidden Bench field have been particularly strong. The 11 wells completed in the second quarter using cemented liners had an average IP rate of 2,872 BOE/d, a 50% increase over the average of our Hidden Bench wells completed with our prior sliding sleeve technology.

Three Forks Second Bench Exploratory Results. In our Tarpon field located in McKenzie County, North Dakota, we completed the Skaar Federal 41-3TFHU in the second bench of the Three Forks formation flowing 6,071 BOE/d on June 7, 2014. The well was completed in a total of 30 stages with a cemented liner and plug-and-perf technology. Whiting holds a 44.8% working interest in the new producer.

We also completed an offsetting well, the Skaar Federal 41-3TFH, in the Upper Three Forks formation flowing 6,634 BOE/d on June 7, 2014. Whiting holds an 82.4% working interest in this well. It appears that there is no communication between the two Skaar wells. Our drilling plans in 2014 focus on drilling spacing units (DSUs) with an average weighted working interest of 83%. Whiting has now recorded the highest initial production rate for both the Upper Three Forks and the second bench of the Three Forks, according to the North Dakota Industrial Commission.

Highlighting recent exploratory activity at our Sanish field was our completion of a well in the second bench of the Three Forks. The Bartleson 44-1-2TFH was tested on May 28, 2014 flowing 1,124 BOE/d. The well was fraced in 29 stages with a cemented liner and plug-and-perf technology. Whiting owns a 100% working interest in the Bartleson well, which was drilled on the west side of the Sanish field.

Slickwater Fracs. Our first slickwater frac job, the Sundheim 21-27-1H well at our Missouri Breaks field in McKenzie County, North Dakota, was completed on August 24, 2013 and had a first 120-day production rate of 374 BOE/d. This was 44% greater than the offsetting well, which was completed using an uncemented liner and sliding sleeve technology. We currently have 11 slickwater fracs either underway or planned for the third quarter of 2014 at the Missouri Breaks, Sanish, Hidden Bench and Pronghorn fields. We also have a slickwater frac planned for our Redtail Niobrara field in the third quarter of 2014. In development mode, we expect the cost of a slickwater frac job to be consistent with a plug-and-perf completion.

Coiled Tubing Fracs. Whiting is the operator of a well that set a record for most stages using a coiled tubing frac, according to NCS Energy Services. The Waldock Federal 14-4-3XH, located in the Sanish field in Mountrail County, North Dakota, was completed on June 26, 2014 in 93 stages and is currently being tested.

 

4


A key benefit of coiled tubing fracs are cycle-time efficiencies in high well density areas. Without the need to drill out the plugs, we have been able to accelerate production by five to seven days per pad where we have tested it in the Williston Basin. We have additional coiled tubing fracs planned for the east side of Sanish field as well as the Tarpon, Pronghorn and Redtail Niobrara fields in the third quarter of 2014.

Denver Julesberg Basin Development

Redtail Niobrara Field. We hold a total of 180,115 gross (128,721 net) acres in our Redtail Niobrara field, located in the Denver Julesberg Basin in Weld County, Colorado. Net production from our Redtail Niobrara field averaged 7,235 BOE/d in the second quarter of 2014, representing a sequential increase of 59% over the 4,550 BOE/d average in the first quarter of 2014.

Our first eight-well pad, the Razor 27I, came on stream on April 15, 2014. The pad drilled four wells to the Niobrara “B” zone and four wells to the Niobrara “A” zone. The production profile for both zones is similar. The pad is currently producing 4,699 BOE/d. On average, the 90-day rate for the Niobrara “A” zone wells was 553 BOE/d, and the 90-day rate for the Niobrara “B” zone wells was 498 BOE/d. We completed all eight wells with cemented liners using plug-and-perf technology. Each well was fracture stimulated in 40 stages with average sand volumes of 6.5 million pounds of sand.

We spud our 30F super pad located in the Horsetail township in early June 2014. This high density pilot will test a 32-well per DSU pattern in the “A”, “B” and “C” zones. If successful, our potential drilling locations at Redtail would increase to more than 6,600 gross wells.

A fourth rig recently arrived at Redtail. This rig will drill approximately six delineation wells on the northern and eastern portions of Redtail. We now have a 3-D seismic survey on this northern acreage that enables us to stay in the targeted “A” and “B” zones. We plan to add a fifth rig in late August 2014 which will be pad capable.

Operated Drilling Rig Count

As of July 15, 2014, 18 operated drilling rigs were active on our properties. The breakdown of our operated rigs was as follows:

 

Region

      

Northern Rockies

     13   

Central Rockies

     3   

Permian Basin

     1   

North Ward Estes

     1   
  

 

 

 

Total

     18   
  

 

 

 

 

5


Other Financial and Operating Results

The following table summarizes the Company’s net production and commodity price realizations for the quarters ended June 30, 2014 and 2013:

 

                                         
     Three Months Ended
June 30,
       
         2014             2013             Change      

Production

      

Oil (MMBbl)

     8.01        6.70        20

NGLs (MMBbl)

     0.79        0.69        13

Natural gas (Bcf)

     7.15        6.62        8

Total equivalent (MMBOE)

     9.99        8.50        18

Average sales price

      

Oil (per Bbl):

      

Price received

   $ 93.03      $     89.15        4

Effect of crude oil hedging

     (0.64 )(1)      (1.05 )(1)   
  

 

 

   

 

 

   

Realized price

   $ 92.39      $ 88.10        5
  

 

 

   

 

 

   

NYMEX

   $ 102.98      $ 94.23        9
  

 

 

   

 

 

   

NGLs (per Bbl):

      

Realized price

   $ 39.30      $ 37.80        4
  

 

 

   

 

 

   

Natural gas (per Mcf):

      

Realized price

   $ 6.95      $ 4.27        63
  

 

 

   

 

 

   

NYMEX

   $ 4.68      $ 4.10        14
  

 

 

   

 

 

   

 

(1)  Whiting paid $5.1 million and $7.0 million in pre-tax cash settlements on its crude oil hedges during the second quarter of 2014 and 2013, respectively. A summary of Whiting’s outstanding hedges is included later in this news release.

 

6


Second Quarter and First Half 2014 Costs and Margins

A summary of production, cash revenues and cash costs on a per BOE basis is as follows:

 

                                                       
     Three Months Ended
June 30,
    Six Months Ended
June 30,
 
     2014      2013     2014      2013  
     (Per BOE, Except Production)  

Production (MMBOE)

     9.99         8.50        18.99         16.52   

Sales price, net of hedging

   $ 82.16       $ 75.88      $ 81.14       $ 75.34   

Lease operating expense

     11.85         12.37        12.27         12.41   

Production tax

     6.89         6.33        6.79         6.36   

General & administrative

     3.56         3.44        3.57         3.52   

Exploration

     1.35         2.86        1.98         2.62   

Cash interest expense

     3.71         2.42        3.89         2.40   

Cash income tax expense (benefit)

     0.74         (0.30     0.44         (0.13
  

 

 

    

 

 

   

 

 

    

 

 

 
   $ 54.06       $ 48.76      $ 52.20       $ 48.16   
  

 

 

    

 

 

   

 

 

    

 

 

 

Second Quarter and First Half 2014 Drilling and Expenditures Summary

The table below summarizes Whiting’s operated and non-operated drilling activity and capital expenditures for the three and six months ended June 30, 2014:

 

     Gross/Net Wells Completed       
     Producing    Non-Producing    Total New
Drilling
   % Success
Rate
   CAPEX
(in MM)
 

Q2 14

   142 / 73.6    0 / 0    142 / 73.6    100% / 100%    $ 768.5 (1) 

6M 14

   285 / 126.5    2 / 1.2    287 / 127.7    99% / 99%    $ 1,451.9 (2) 

 

(1)  Includes $9.8 million for land and $44.1 million for facilities.
(2)  Includes $40.1 million for land and $84.6 million for facilities.

Outlook for Third Quarter and Full-Year 2014

The following table provides guidance for the third quarter and full-year 2014 based on current forecasts, including Whiting’s full-year 2014 capital budget of $2.8 billion.

 

     Guidance
     Third Quarter
2014
   Full-Year
2014

Production (MMBOE)

   10.50 - 10.90    40.70 - 41.30

Lease operating expense per BOE

   $11.25 - $12.00    $11.60 - $11.90

General and admin. expense per BOE

   $3.30 - $3.70    $3.40 - $3.60

Interest expense per BOE

   $3.50 - $3.80    $3.80 - $4.00

Depr., depletion and amort. per BOE

   $26.50 - $27.25    $26.20 - $27.00

Prod. taxes (% of sales revenue)

   8.25% - 8.45%    8.25% - 8.45%

Oil price differentials to NYMEX per Bbl(1)

   ($9.00) - ($11.00)    ($8.50) - ($10.50)

Gas price premium to NYMEX per Mcf(2)

   $1.00 - $ 2.00    $1.00 - $ 2.00

 

(1)  Does not include the effect of NGLs.
(2)  Includes the effect of Whiting’s fixed-price gas contracts. Please refer to fixed-price gas contracts later in this news release.

 

7


Commodity Derivative Contracts

The following summarizes Whiting’s crude oil hedges as of July 1, 2014:

 

Derivative Instrument

   Hedge Period    Contracted Volume
(Bbls per Month)
   Weighted Average
NYMEX Price
(per Bbl)
   As a Percentage of
June 2014
Oil Production

Three-way collars(1)

   2014         
   Q3        1,480,000    $71.82 - $85.68 - $103.85    53.5%
   Q4        1,480,000    $71.82 - $85.68 - $103.85    53.5%
   2015         
   Q1        100,000    $70.00 - $85.00 - $107.90    3.6%
   Q2        100,000    $70.00 - $85.00 - $107.90    3.6%
   Q3        100,000    $70.00 - $85.00 - $107.90    3.6%
   Q4        100,000    $70.00 - $85.00 - $107.90    3.6%

Collars

   2014         
   Q3        4,060    $80.00 - $122.50    <1%
   Q4        3,970    $80.00 - $122.50    <1%

 

(1)  A three-way collar is a combination of options: a sold call, a purchased put and a sold put. The sold call establishes a maximum price (ceiling) we will receive for the volumes under contract. The purchased put establishes a minimum price (floor), unless the market price falls below the sold put (sub-floor), at which point the minimum price would be NYMEX plus the difference between the purchased put and the sold put strike price.

The following summarizes Whiting’s fixed-price natural gas contracts as of July 1, 2014:

 

Hedge

Period

   Contracted Volume
(MMBtu per Day)
   Weighted Average
Contracted Price
(per MMBtu)
     As a Percentage of
June 2014
Gas Production

2014

        

Q3

   11,000    $ 5.49       13.4%

Q4

   11,000    $ 5.49       13.4%

 

8


Whiting also has the following fixed-differential crude oil sales contracts in place as of July 1, 2014:

 

Period

   Gross
Contracted Volume
(Bbls per Day)
   Differential
from NYMEX
(per Bbl)

2015

   25,000      $ 4.75  

2016

   30,000      $ 4.75  

2017

   35,000      $ 4.75  

2018

   40,000      $ 4.75  

2019

   45,000      $ 4.75  

Period

   Gross
Contracted Volume
(Bbls per Day)
   Differential
from NYMEX
(per Bbl)(1)

07/2015 to 12/2015

   20,000        $5.00 - $6.00  

01/2016 to 12/2016

   20,000        $5.00 - $6.00  

01/2017 to 12/2017

   20,000        $5.00 - $6.00  

01/2018 to 12/2018

   20,000        $5.00 - $6.00  

01/2019 to 12/2019

   20,000        $5.00 - $6.00  

01/2020 to 06/2020

   20,000        $5.00 - $6.00  

 

(1) The future production volumes in the table above will be sold at a price equal to NYMEX less certain fixed differentials depending on the delivery methods specified in the contract. Based on prevailing storage and transportation costs, we estimate a fixed differential of $5.00 to $6.00 per barrel below NYMEX.

 

9


Selected Operating and Financial Statistics

 

                                                                           
     Three Months Ended
June 30,
    Six Months Ended
June 30,
 
     2014     2013     2014     2013  

Selected operating statistics:

        

Production

        

Oil, MBbl

     8,010        6,701        15,251        12,951   

NGLs, MBbl

     787        694        1,435        1,404   

Natural gas, MMcf

     7,150        6,617        13,852        12,988   

Oil equivalents, MBOE

     9,988        8,498        18,994        16,520   

Average prices

        

Oil per Bbl (excludes hedging)

   $ 93.03      $ 89.15      $ 91.04      $ 88.65   

NGLs per Bbl

   $ 39.30      $ 37.80      $ 45.47      $ 40.20   

Natural gas per Mcf

   $ 6.95      $ 4.27      $ 6.73      $ 4.04   

Per BOE data

        

Sales price (including hedging)

   $ 82.16      $ 75.88      $ 81.14      $ 75.34   

Lease operating

   $ 11.85      $ 12.37      $ 12.27      $ 12.41   

Production taxes

   $ 6.89      $ 6.33      $ 6.79      $ 6.36   

Depreciation, depletion and amortization

   $ 26.88      $ 26.29      $ 26.52      $ 25.70   

General and administrative

   $ 3.56      $ 3.44      $ 3.57      $ 3.52   

Selected financial data:

        

(In thousands, except per share data)

        

Total revenues and other income

   $ 835,622      $ 663,569      $ 1,575,871      $ 1,276,940   

Total costs and expenses

   $ 584,279      $ 455,598      $ 1,139,116      $ 931,205   

Net income available to common shareholders

   $ 151,444      $ 134,687      $ 260,513      $ 220,681   

Earnings per common share, basic

   $ 1.27      $ 1.14      $ 2.19      $ 1.87   

Earnings per common share, diluted

   $ 1.26      $ 1.14      $ 2.17      $ 1.86   

Average shares outstanding, basic

     118,968        117,930        118,946        117,859   

Average shares outstanding, diluted

     120,027        118,901        120,045        118,929   

Net cash provided by operating activities

   $ 567,769      $ 442,617      $ 891,666      $ 740,231   

Net cash used in investing activities

   $ (742,568   $ (574,590   $ (1,322,122   $ (1,203,081

Net cash provided by (used in) financing activities

   $ (4,555   $ 147,103      $ (41,921   $ 441,362   

 

10


Selected Financial Data

For further information and discussion on the selected financial data below, please refer to Whiting Petroleum Corporation’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2014, to be filed with the Securities and Exchange Commission.

WHITING PETROLEUM CORPORATION

CONSOLIDATED BALANCE SHEETS (unaudited)

(In thousands)

 

                                             
     June 30,
2014
    December 31,
2013
 

ASSETS

    

Current assets:

    

Cash and cash equivalents

   $ 227,083      $ 699,460   

Accounts receivable trade, net

     464,474        341,177   

Prepaid expenses and other

     41,566        28,981   
  

 

 

   

 

 

 

Total current assets

     733,123        1,069,618   
  

 

 

   

 

 

 

Property and equipment:

    

Oil and gas properties, successful efforts method

     11,421,570        10,065,150   

Other property and equipment

     234,116        206,385   
  

 

 

   

 

 

 

Total property and equipment

     11,655,686        10,271,535   

Less accumulated depreciation, depletion and amortization

     (3,158,917     (2,676,490
  

 

 

   

 

 

 

Total property and equipment, net

     8,496,769        7,595,045   

Debt issuance costs

     47,845        48,530   

Other long-term assets

     81,231        120,277   
  

 

 

   

 

 

 

TOTAL ASSETS

   $ 9,358,968      $ 8,833,470   
  

 

 

   

 

 

 

 

11


WHITING PETROLEUM CORPORATION

CONSOLIDATED BALANCE SHEETS (unaudited)

(In thousands, except share and per share data)

 

                                             
     June 30,
2014
     December 31,
2013
 

LIABILITIES AND EQUITY

     

Current liabilities:

     

Accounts payable trade

     144,801         107,692   

Accrued capital expenditures

     216,076         158,739   

Accrued liabilities and other

     219,525         214,109   

Revenues and royalties payable

     214,147         198,558   

Taxes payable

     69,505         50,052   

Accrued interest

     43,057         44,405   

Derivative liabilities

     24,044         3,482   

Deferred income taxes

     10,324         648   
  

 

 

    

 

 

 

Total current liabilities

     941,479         777,685   

Long-term debt

     2,653,512         2,653,834   

Deferred income taxes

     1,436,447         1,278,030   

Production Participation Plan liability

     —           87,503   

Asset retirement obligations

     157,243         116,442   

Deferred gain on sale

     68,852         79,065   

Other long-term liabilities

     4,300         4,212   
  

 

 

    

 

 

 

Total liabilities

     5,261,833         4,996,771   
  

 

 

    

 

 

 

Commitments and contingencies

     

Equity:

     

Common stock, $0.001 par value, 300,000,000 shares authorized; 120,443,221 issued and 118,981,965 outstanding as of June 30, 2014 and 120,101,555 issued and 118,657,245 outstanding as of December 31, 2013

     120         120   

Additional paid-in capital

     1,583,501         1,583,542   

Retained earnings

     2,505,418         2,244,905   
  

 

 

    

 

 

 

Total Whiting shareholders’ equity

     4,089,039         3,828,567   

Noncontrolling interest

     8,096         8,132   
  

 

 

    

 

 

 

Total equity

     4,097,135         3,836,699   
  

 

 

    

 

 

 

TOTAL LIABILITIES AND EQUITY

   $ 9,358,968       $ 8,833,470   
  

 

 

    

 

 

 

 

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WHITING PETROLEUM CORPORATION

CONSOLIDATED STATEMENTS OF INCOME (unaudited)

(In thousands, except per share data)

 

                                                                       
     Three Months Ended
June 30,
    Six Months Ended
June 30,
 
     2014     2013     2014      2013  

REVENUES AND OTHER INCOME:

         

Oil, NGL and natural gas sales

   $ 825,760      $ 651,868      $ 1,547,010       $ 1,256,982   

Loss on hedging activities

     —          (437     —           (648

Amortization of deferred gain on sale

     7,473        7,954        15,217         15,930   

Gain on sale of properties

     1,796        3,387        12,355         3,432   

Interest income and other

     593        797        1,289         1,244   
  

 

 

   

 

 

   

 

 

    

 

 

 

Total revenues and other income

     835,622        663,569        1,575,871         1,276,940   
  

 

 

   

 

 

   

 

 

    

 

 

 

COSTS AND EXPENSES:

         

Lease operating

     118,361        105,080        233,147         204,958   

Production taxes

     68,857        53,814        128,887         105,085   

Depreciation, depletion and amortization

     268,509        223,446        503,774         424,605   

Exploration and impairment

     31,512        43,393        73,619         80,673   

General and administrative

     35,555        29,213        67,889         58,098   

Interest expense

     39,045        23,121        81,189         44,591   

Change in Production Participation Plan liability

     (3,636     7,723        —           12,130   

Commodity derivative (gain) loss, net

     26,076        (30,192     50,611         1,065   
  

 

 

   

 

 

   

 

 

    

 

 

 

Total costs and expenses

     584,279        455,598        1,139,116         931,205   
  

 

 

   

 

 

   

 

 

    

 

 

 

INCOME BEFORE INCOME TAXES

     251,343        207,971        436,755         345,735   

INCOME TAX EXPENSE (BENEFIT):

         

Current

     7,355        (2,511     8,355         (2,089

Deferred

     92,562        75,538        167,923         126,636   
  

 

 

   

 

 

   

 

 

    

 

 

 

Total income tax expense

     99,917        73,027        176,278         124,547   
  

 

 

   

 

 

   

 

 

    

 

 

 

NET INCOME

     151,426        134,944        260,477         221,188   

Net loss attributable to noncontrolling interest

     18        12        36         31   
  

 

 

   

 

 

   

 

 

    

 

 

 

NET INCOME AVAILABLE TO SHAREHOLDERS

     151,444        134,956        260,513         221,219   

Preferred stock dividends

     —          (269     —           (538
  

 

 

   

 

 

   

 

 

    

 

 

 

NET INCOME AVAILABLE TO COMMON SHAREHOLDERS

   $ 151,444      $ 134,687      $ 260,513       $ 220,681   
  

 

 

   

 

 

   

 

 

    

 

 

 

EARNINGS PER COMMON SHARE:

         

Basic

   $ 1.27      $ 1.14      $ 2.19       $ 1.87   
  

 

 

   

 

 

   

 

 

    

 

 

 

Diluted

   $ 1.26      $ 1.14      $ 2.17       $ 1.86   
  

 

 

   

 

 

   

 

 

    

 

 

 
         

WEIGHTED AVERAGE SHARES OUTSTANDING:

         

Basic

     118,968        117,930        118,946         117,859   
  

 

 

   

 

 

   

 

 

    

 

 

 

Diluted

     120,027        118,901        120,045         118,929   
  

 

 

   

 

 

   

 

 

    

 

 

 

 

13


WHITING PETROLEUM CORPORATION

Reconciliation of Net Income Available to Common Shareholders to

Adjusted Net Income Available to Common Shareholders

(In thousands, except per share data)

 

                                                           
     Three Months Ended
June 30,
    Six Months Ended
June 30,
 
     2014     2013     2014     2013  

Net income available to common shareholders

   $ 151,444      $ 134,687      $ 260,513      $ 220,681   

Adjustments net of tax:

        

Amortization of deferred gain on sale

     (4,708     (5,002     (9,587     (10,017

Gain on sale of properties

     (1,132     (2,130     (7,784     (2,158

Impairment expense

     11,369        11,979        22,700        23,557   

Change in Production Participation Plan liability

     (2,291     4,856        —          7,627   

Total measure of derivative (gain) loss reported under U.S. GAAP

     16,428        (18,710     31,885        1,077   

Total net cash settlements paid on commodity derivatives during the period

     (3,229     (4,416     (3,696     (7,751
  

 

 

   

 

 

   

 

 

   

 

 

 

Adjusted net income (1)

   $ 167,881      $ 121,264      $ 294,031      $ 233,016   
  

 

 

   

 

 

   

 

 

   

 

 

 

Adjusted net income available to common shareholders per share, basic

   $ 1.41      $ 1.03      $ 2.47      $ 1.98   
  

 

 

   

 

 

   

 

 

   

 

 

 

Adjusted net income available to common shareholders per share, diluted

   $ 1.40      $ 1.02      $ 2.45      $ 1.96   
  

 

 

   

 

 

   

 

 

   

 

 

 

 

(1)  Adjusted Net Income Available to Common Shareholders is a non-GAAP financial measure. Management believes it provides useful information to investors for analysis of Whiting’s fundamental business on a recurring basis. In addition, management believes that Adjusted Net Income Available to Common Shareholders is widely used by professional research analysts and others in valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry, and many investors use the published research of industry research analysts in making investment decisions. Adjusted Net Income Available for Common Shareholders should not be considered in isolation or as a substitute for net income, income from operations, net cash provided by operating activities or other income, cash flow or liquidity measures under U.S. GAAP and may not be comparable to other similarly titled measures of other companies.

 

14


WHITING PETROLEUM CORPORATION

Reconciliation of Net Cash Provided by Operating Activities to Discretionary Cash Flow

(In thousands)

 

                                                                       
     Three Months Ended
June 30,
    Six Months Ended
June 30,
 
     2014     2013     2014     2013  

Net cash provided by operating activities

   $ 567,769      $ 442,617      $ 891,666      $ 740,231   

Exploration

     13,466        24,343        37,588        43,209   

Exploratory dry hole costs

     (70     (11,628     (3,622     (11,628

Changes in working capital

     (24,978     (14,191     112,516        70,668   

Preferred stock dividends paid

     —          (269     —          (538
  

 

 

   

 

 

   

 

 

   

 

 

 

Discretionary cash flow (1)

   $ 556,187      $ 440,872      $ 1,038,148      $ 841,942   
  

 

 

   

 

 

   

 

 

   

 

 

 

 

(1)  Discretionary cash flow is a non-GAAP measure. Discretionary cash flow is presented because management believes it provides useful information to investors for analysis of the Company’s ability to internally fund acquisitions, exploration and development. Discretionary cash flow should not be considered in isolation or as a substitute for net income, income from operations, net cash provided by operating activities or other income, cash flow or liquidity measures under U.S. GAAP and may not be comparable to other similarly titled measures of other companies.

 

15


Conference Call

The Company’s management will host a conference call with investors, analysts and other interested parties on Thursday, July 31, 2014 at 11:00 a.m. EDT (10:00 a.m. CDT, 9:00 a.m. MDT) to discuss Whiting’s second quarter 2014 financial and operating results. Please call (877) 415-3182 (U.S./Canada) or (857) 244-7325 (International) to be connected to the call and enter the pass code 58389225. Access to a live internet broadcast will be available at http://www.whiting.com by clicking on the button labeled “Kodiak Acquisition” on the home page. Slides for the conference call will be available at the same location beginning at 11:00 a.m. (EDT) on July 31, 2014.

A replay will be available on Friday, August 1, 2014 and continuing through Friday, August 8, 2014. You may access this replay at (888) 286-8010 (U.S./Canada) or (617) 801-6888 (International) and entering the pass code 38451478.

About Whiting Petroleum Corporation

Whiting Petroleum Corporation, a Delaware corporation, is an independent oil and gas company that explores for, develops, acquires and produces crude oil, natural gas and natural gas liquids primarily in the Rocky Mountain and Permian Basin regions of the United States. The Company’s largest projects are in the Bakken and Three Forks plays in North Dakota and its Enhanced Oil Recovery field in Texas. The Company trades publicly under the symbol WLL on the New York Stock Exchange. For further information, please visit http://www.whiting.com.

Forward-Looking Statements

This news release contains statements that we believe to be “forward-looking statements” within the meaning of Section 21E of the Securities Exchange Act of 1934. All statements other than historical facts, including, without limitation, statements regarding our future financial position, business strategy, projected revenues, earnings, costs, capital expenditures and debt levels, and plans and objectives of management for future operations, are forward-looking statements. When used in this news release, words such as we “expect,” “intend,” “plan,” “estimate,” “anticipate,” “believe” or “should” or the negative thereof or variations thereon or similar terminology are generally intended to identify forward-looking statements. Such forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those expressed in, or implied by, such statements.

These risks and uncertainties include, but are not limited to: the ability to obtain shareholder, court and regulatory approval of our proposed acquisition (the “Acquisition”) of Kodiak Oil & Gas Corp. (“Kodiak”); the ability to complete the proposed Acquisition on anticipated terms and timetable; Whiting’s and Kodiak’s ability to integrate successfully after the Acquisition and achieve anticipated benefits from the Acquisition; the possibility that various closing conditions for the Acquisition may not be satisfied or waived; declines in oil, NGL or natural gas prices; our level of success in exploration, development and production activities; adverse weather conditions that may negatively impact development or production activities; the timing of our exploration and development expenditures; our ability to obtain sufficient quantities of CO2 necessary to carry out our enhanced oil recovery projects; inaccuracies of our reserve estimates or our assumptions underlying them; revisions to reserve estimates as a result of changes in commodity prices; impacts to financial statements as a result of impairment write downs; risks related to our level of indebtedness and periodic redeterminations of the borrowing base under our credit agreement; our ability to generate sufficient cash flows from operations to meet the internally funded portion of our capital expenditures budget; our ability to obtain external capital to finance exploration and development operations and acquisitions; federal and state initiatives relating to the regulation of hydraulic fracturing; the potential impact of federal debt reduction initiatives and tax reform legislation being considered by the U.S. Federal Government that could have a negative effect on the oil and gas industry; our ability to identify and complete acquisitions and to successfully integrate acquired businesses; unforeseen underperformance of or liabilities associated with acquired properties; our ability to successfully complete potential asset dispositions and the risks related thereto; the impacts of hedging on our results of operations; failure of our properties to yield oil or gas in commercially viable quantities; uninsured or underinsured losses resulting from our oil and gas operations; our inability to access oil and gas markets due to market conditions or operational impediments; the impact and costs of compliance with laws and regulations governing our oil and gas operations; our ability to replace our oil and natural gas reserves; any loss of our senior management or technical personnel; competition in the oil and gas industry in the regions in which we operate; risks arising out of our hedging transactions; and other risks described under the caption “Risk Factors” in our Annual Report on Form 10-K for the period ended December 31, 2013. We assume no obligation, and disclaim any duty, to update the forward-looking statements in this news release.

 

16


Important Additional Information and Where to Find It

This communication does not constitute an offer to sell or the solicitation of an offer to buy any securities or a solicitation of a vote or proxy. The proposed Acquisition anticipates that the Whiting shares to be issued pursuant to the Acquisition will be exempt from registration under the United States Securities Act of 1933, as amended (the “Securities Act”), pursuant to Section 3(a)(10) of the Securities Act. Consequently, the Whiting shares will not be registered under the Securities Act or any state securities laws. In connection with the proposed Acquisition, Whiting and Kodiak intend to file relevant materials with the SEC and other governmental or regulatory authorities, including a joint proxy statement and circular. INVESTORS ARE URGED TO READ THE JOINT PROXY STATEMENT AND CIRCULAR AND ANY OTHER RELEVANT MATERIALS WHEN THEY BECOME AVAILABLE BECAUSE THEY WILL CONTAIN IMPORTANT INFORMATION ABOUT WHITING, KODIAK AND THE PROPOSED ACQUISITION. The joint proxy statement and circular and certain other relevant materials (when they become available) and other documents filed by Whiting or Kodiak with the SEC may be obtained free of charge at the SEC’s website at http://www.sec.gov. In addition, investors may obtain copies of these documents (when they become available) free of charge by written request to Whiting Investor Relations, 1700 Broadway, Suite 2300, Denver, CO 80290-2300 or calling (303) 390-4051 or by written request to Kodiak Investor Relations, 1625 Broadway, Suite 250, Denver, CO 80202 or calling (303) 592-8030.

Participants in the Solicitation

Whiting, Kodiak and their respective executive officers and directors may be deemed to be participants in the solicitation of proxies in connection with the proposed Acquisition. Information about the executive officers and directors of Whiting and the number of shares of Whiting’s common stock beneficially owned by such persons is set forth in the proxy statement for Whiting’s 2014 Annual Meeting of Stockholders which was filed with the SEC on March 23, 2014, and Whiting’s Annual Report on Form 10-K for the period ended December 31, 2013. Information about the executive officers and directors of Kodiak and the number of Kodiak’s ordinary shares beneficially owned by such persons is set forth in the proxy statement for Kodiak’s 2014 Annual Meeting of Shareholders which was filed with the SEC on May 9, 2014, and Kodiak’s Annual Report on Form 10-K for the period ended December 31, 2013. Investors may obtain additional information regarding the direct and indirect interests of Whiting, Kodiak and their respective executive officers and directors in the Acquisition by reading the joint proxy statement and circular regarding the Acquisition when it becomes available.

Contact

Whiting

Eric Hagen

(303) 390-4051

eric.hagen@whiting.com

 

17