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Investor Alert

press release

Feb. 24, 2021, 4:10 p.m. EST

Callon Petroleum Company Announces Fourth Quarter and Full Year 2020 Results and Provides 2021 Plan Focused on Free Cash Flow and Debt Reduction Initiatives

HOUSTON, Feb. 24, 2021 /PRNewswire/ -- Callon Petroleum Company /zigman2/quotes/201917664/composite CPE -3.23% ("Callon" or the "Company") today reported results of operations for the three months and full-year ended December 31, 2020.

Presentation slides accompanying this earnings release are available on the Company's website at www.callon.com located on the "Presentations" page within the Investors section of the site.

2020 Highlights

  • Full-year 2020 production of 101.6 MBoe/d (63% oil), an increase of 146% over 2019 volumes

  • Year-end proved reserves of 475.9 MMBoe (61% oil)

  • Generated net cash provided by operating activities of $559.8 million and adjusted free cash flow [1] of $10.7 million, including net cash provided by operating activities of $368.1 million and $122.6 million of adjusted free cash flow [1] generation over the last three quarters

  • Loss available to common stockholders of $2.5 billion, or $63.79 per diluted share, driven by impairments of evaluated oil and gas properties of $2.5 billion, adjusted EBITDA [1] of $709.7 million, and adjusted income [1] of $117.1 million or $2.86 per diluted share

  • Lowered average drilling and completion cost per lateral foot by approximately 35% from 2019 comparable well costs, driving total operational capital expenditures of $488.6 million, meaningfully below budgeted levels

  • Reduced total cash general and administrative expenses by more than 60% from pro forma 2019 [2] levels

  • Lowered annual lease operating expense by more than $30 million from pro forma 2019 [2] levels through effective implementation of field best practices

  • Asset monetization proceeds and debt exchanges reduced total debt balances by approximately $350 million since the second quarter of 2020

Fourth Quarter 2020 Highlights

  • Fourth quarter 2020 production of 94.9 MBoe/d (62% oil), an increase of 103% over fourth quarter 2019 volumes and a sequential decrease of 7% including the impact of completed divestitures

  • Generated $134.6 million of net cash provided by operating activities and adjusted free cash flow [1] of $24.4 million

  • Loss available to common stockholders of $505.1 million, or $12.71 per diluted share, driven by an impairment of evaluated oil and gas properties of $585.8 million, adjusted EBITDA [1] of $167.8 million, and adjusted income [1] of $42.8 million or $1.00 per diluted share

2021 Capital Plan Highlights

  • Operational capital budget of up to $430 million, a 12% reduction relative to 2020 spending, with approximately 70% allocated to Permian activity

  • Annual production guidance of 90 - 92 MBoe/d (63% oil) inclusive of estimated winter storm impacts of approximately 2 MBoe/d for the full year 2021

  • Expected adjusted free cash flow [1] generation of approximately $150 million at $50/Bbl oil (WTI benchmark)

Joe Gatto, President and Chief Executive Officer commented, "In a year marked by extraordinary volatility in commodity prices and workplace challenges created by the COVID-19 pandemic, our newly integrated team executed flawlessly on a revamped set of operational and financial initiatives that ultimately delivered over $120 million of adjusted free cash flow since the beginning of the second quarter, dramatically improving our liquidity and absolute debt position. Importantly, these accomplishments were complemented by significant achievements related to employee safety and environmental emissions."

He continued, "Our medium-term development plans are squarely focused on free cash flow generation and absolute debt reduction. Given our leading operating margins and low-cost resource base, the magnitude and pace of improvements in financial strength from organic cash flows are highly differentiated in the sector. Our 2021 capital budget, inclusive of capitalized expenses, implies a reinvestment rate [3] of approximately 75% of discretionary cash flow at $50 per barrel WTI price and a free cash flow breakeven price of approximately $40 per barrel. We will continue to manage our future capital reinvestment rate [3] within a targeted range of 65% to 75% under a range of pricing environments, which is expected to generate adjusted free cash flow in a range of $500 to $800 million over the next three years assuming WTI oil prices of $50 to $60 per barrel. In addition, we are targeting asset monetizations of approximately $125 to $225 million in 2021 to further our debt reduction goals, meeting our original 2020 total divestiture targets after including transactions completed last year. As divestiture market conditions continue to improve, we are evaluating opportunities for incremental, credit enhancing monetizations above our targeted levels."

Environmental, Social, and Governance ("ESG") Updates

Callon advanced its sustainability initiatives during 2020 with the Company achieving numerous milestones as detailed below:

  • Issued an inaugural SASB aligned sustainability report

  • Reduced flared natural gas volumes by 44%

  • Achieved a 66% reduction in spill volumes

  • Increased recycled water usage by 10%

  • Set a new Callon record for safety with a total recordable incident rate of under 0.55

  • Named a top Houston workplace for the fourth straight year by the Houston Chronicle

  • Supported schools, food banks and first responders in our local communities during the challenges of the global pandemic

  • Enhanced board oversight of ESG by expanding the remit of the Nominating and ESG Committee

Callon continues to advance various sustainability efforts and expects to disclose new long-term targets for GHG emissions reductions and a revamped executive compensation program aligned with investor and corporate priorities in the near future.

Operations Update and Outlook

At December 31, 2020, Callon had 1,496 gross (1,320.6 net) horizontal wells producing from established flow units in the Permian and Eagle Ford. Net daily production for the three months ended December 31, 2020 grew 103% to 94.9 MBoe/d (62% oil) as compared to the same period of 2019. Full year production for 2020 averaged 101.6 MBoe/d (63% oil) reflecting growth of 146% over 2019 volumes.

For the three months ended December 31, 2020, Callon drilled 22 gross (20.0 net) horizontal wells and placed a combined 16 gross (14.3 net) horizontal wells on production. Wells placed on production during the quarter were completed in the Lower Spraberry and Wolfcamp A in the Midland Basin and the Wolfcamp A and Wolfcamp C in the Delaware Basin.

Recently, severe winter storms affected field operations in both the Permian and Eagle Ford resulting in the shut-in of nearly 100% of our operated production. Currently, we have returned nearly all of our Eagle Ford and Midland Basin wells to production and expect to have all of our Delaware well production returned by the end of February. The estimated annualized impact of these deferrals is approximately 2,000 Boe/d. This has been reflected in our updated production guidance for 2021. The impact to our drilling and completion operations were not significant enough to alter our expectations for the full year development schedule and any additional operational costs are currently reflected in our lease operating expense guidance.

Currently, the Company has three active rigs with one each in the Midland, Delaware, and Eagle Ford. The Company recently deployed a second completion crew and has operations taking place in the Delaware and Eagle Ford.

2021 Capital Expenditures Budget

Callon has established an operational capital expenditure budget of $430.0 million for 2021 with approximately 80% of spending directed towards drilling, completion and equipment expenditures. The reduction of approximately $60 million from 2020 levels reflects a decrease in the number of drilled wells as well as a full year of achieved capital synergies. Roughly 70% of this development capital will be spent on Permian activity with the remaining balance allocated to the Eagle Ford. Permian development activity will predominantly feature co-development of the Wolfcamp A and B in the Delaware and the Lower Spraberry and Wolfcamp A in the Midland. The Eagle Ford program remains focused solely on the primary target zone, the Lower Eagle Ford Shale, as technical evaluation continues on Austin Chalk potential for future delineation. In total, the Company expects to drill 55 to 65 gross wells and complete 90 to 100 gross wells.

Our scaled development plan for 2021 will continue to employ our life of field development philosophy and benefit from our balanced capital deployment strategy. We entered the year with a robust backlog of drilled uncompleted wells ("DUCs"), after drilling over 90 wells in 2020, which will allow us to complete approximately 55 wells in the first half of the year. Although at a reduced number from year end 2020, we now plan to maintain a meaningful DUC inventory heading into 2022 to provide operational flexibility to execute across a range of development planning scenarios. The capital expenditures associated with this higher DUC inventory contributed to the majority of the approximate $30 million increase relative to our previous 2021 capital estimates, in addition to selective project size increases to improve capital efficiency and resource recovery. These schedule refinements will position Callon for an improved production trajectory in the medium term, adhering to our reinvestment rate parameters, to increase free cash flow generation potential.

The 2021 capital plan leverages the structural savings and operational efficiencies achieved during 2020 from shared best practices following the integration of Callon and Carrizo. Callon's ability to reduce the average well cost by more than 35% on a lateral foot basis since 2019 has yielded significant improvements in capital efficiency. Lower capital costs paired with an improved operating cost structure and moderated development program are expected to provide a foundation of durable free cash flow generated by a program that optimizes recoverable value while avoiding over-capitalization of the resource base.

The remainder of our full year 2021 outlook is provided later in this release under the section titled "2021 Guidance."

Capital Expenditures

For the year ended December 31, 2020, Callon incurred $488.6 million in operational capital expenditures on an accrual basis as compared to $515.1 million in 2019. For the three months ended December 31, 2020, the Company incurred $87.5 million in operational capital expenditures on an accrual basis, which represented a $49.1 million increase from the third quarter of 2020. Total capital expenditures, inclusive of capitalized expenses, are detailed below on an accrual and cash basis:



Three Months Ended December 31, 2020


Operational
Capitalized
Capitalized
Total Capital


Capital (a)
Interest
G&A
Expenditures


(In thousands)
Cash basis (b)
$77,742

$25,201

$6,465

$109,408
Timing adjustments (c)
8,317

(2,187)



6,130
Non-cash items
1,429



2,390

3,819
   Accrual basis
$87,488

$23,014

$8,855

$119,357


(a)  Includes seismic, land, technology, and other items.
(b)  Cash basis is presented here to help users of financial information reconcile amounts from the cash flow statement to the balance sheet by accounting for timing related changes in working capital that align with our development pace and rig count.
(c)  Includes timing adjustments related to cash disbursements in the current period for capital expenditures incurred in the prior period.

Operating and Financial Results

The following table presents summary information for the periods indicated:



Three Months Ended


December 31, 2020
September 30, 2020
December 31, 2019
Total production





Oil (MBbls)





Permian
3,445

3,441

2,934
Eagle Ford
1,980

2,434

300
  Total oil (MBbls)
5,425

5,875

3,234







Natural gas (MMcf)





Permian
7,474

7,868

5,296
Eagle Ford
2,264

2,393

234
  Total natural gas (MMcf)
9,738

10,261

5,530







NGLs (MBbls)





Permian
1,331

1,423

93
Eagle Ford
353

379

42
  Total NGLs (MBbls)
1,684

1,802

135







Total production (MBoe)





Permian
6,022

6,175

3,910
Eagle Ford
2,710

3,212

381
  Total barrels of oil equivalent (MBoe)
8,732

9,387

4,291







Total daily production (Boe/d)





Permian
65,459

67,117

42,500
Eagle Ford
29,455

34,912

4,141
  Total barrels of oil equivalent (Boe/d)
94,914

102,029

46,641
Oil as % of total daily production
62 %
63 %
75 %


Three Months Ended


December 31, 2020
September 30, 2020
December 31, 2019
Average realized sales price (excluding impact of settled derivatives)





Oil (per Bbl)





Permian
$41.02

$39.42

$56.31
Eagle Ford
41.12

39.44

59.57
  Total oil (per Bbl)
$41.06

$39.43

$56.61







Natural gas (per Mcf)





Permian
$1.68

$1.31

$1.96
Eagle Ford
2.65

1.99

2.44
  Total natural gas (per Mcf)
$1.91

$1.47

$1.98







NGL (per Bbl)





Permian
$15.00

$12.68

$16.58
Eagle Ford
16.16

13.13

12.69
  Total NGL (per Bbl)
$15.24

$12.78

$15.37







Average realized sales price (per Boe)





Permian
$28.87

$26.55

$45.30
Eagle Ford
34.36

32.92

49.81
  Total average realized sales price (per Boe)
$30.57

$28.73

$45.70







Average realized sales price





Oil (per Bbl)
$39.62

$39.00

$55.33
Natural gas (per Mcf)
1.89

1.17

2.12
NGLs (per Bbl)
15.24

12.78

15.37
   Total average realized sales price (per Boe)
$29.66

$28.14

$44.92







Revenues (in thousands)(a)





Oil





Permian
$141,320

$135,648

$165,199
Eagle Ford
81,413

96,006

17,872
  Total oil
222,733

231,654

183,071







Natural gas





Permian
12,560

10,271

10,377
Eagle Ford
6,001

4,763

572
  Total natural gas
18,561

15,034

10,949







NGLs





Permian
19,964

18,049

1,542
Eagle Ford
5,704

4,976

533
  Total NGLs
25,668

23,025

2,075







Total revenues





Permian
173,844

163,968

177,118
Eagle Ford
93,118

105,745

18,977
  Total revenues
$266,962

$269,713

$196,095









Three Months Ended


December 31, 2020
September 30, 2020
December 31, 2019
Additional per Boe data





Sales price (b)





Permian
$28.87

$26.55

$45.30
Eagle Ford
34.36

32.92

49.81
  Total sales price
$30.57

$28.73

$45.70







Lease operating expense





Permian
$4.43

$4.38

$5.66
Eagle Ford
6.77

5.86

8.38
  Total lease operating expense
$5.15

$4.89

$5.90







Production and ad valorem taxes





Permian
$1.71

$1.57

$2.04
Eagle Ford
2.29

2.00

2.29
  Total production and ad valorem taxes
$1.89

$1.72

$2.06







Gathering, transportation and processing





Permian
$2.42

$2.55

$—
Eagle Ford
2.25

2.00


  Total gathering, transportation and processing
$2.37

$2.36

$—







Operating margin





Permian
$20.31

$18.05

$37.60
Eagle Ford
23.05

23.06

39.14
  Total operating margin
$21.16

$19.76

$37.74







Depletion, depreciation and amortization
$11.00

$12.17

$14.30
General and administrative
$1.22

$0.88

$3.18
Adjusted G&A 1





Cash component (c)
$0.86

$0.87

$2.41
Non-cash component
$0.07

$0.18

$0.53


(a)  Excludes sales of oil and gas purchased from third parties and sold to our customers.
(b)  Excludes the impact of settled derivatives.
(c)  Excludes the change in fair value and amortization of share-based incentive awards and other non-recurring expenses.

Revenue.   For the quarter ended December 31, 2020, Callon reported total revenue of $267.0 million, which excluded revenue from sales of commodities purchased from a third-party of $29.0 million. Revenues including the gain or loss from the settlement of derivative contracts ("Adjusted Total Revenue" [1] ) were $259.0 million, reflecting the impact of an $8.0 million loss from the settlement of derivative contracts. Average daily production for the quarter was 94.9 MBoe/d compared to average daily production of 102.0 MBoe/d in the third quarter of 2020. Average realized prices, including and excluding the effects of hedging, are detailed above.

Commodity Derivatives.  For the quarter ended December 31, 2020, the net (gain) loss on commodity derivative contracts includes the following (in thousands):



Three Months Ended


December 31, 2020
(Gain) loss on oil derivatives
$70,317
(Gain) loss on natural gas derivatives
(3,936)
(Gain) loss on NGL derivatives
8
(Gain) loss on commodity derivative contracts
$66,389

For the quarter ended December 31, 2020, the cash (paid) received for commodity derivative settlements includes the following (in thousands):



Three Months Ended


December 31, 2020
Cash (paid) received on oil derivatives
($2,100)
Cash (paid) received on natural gas derivatives
(784)
Cash (paid) received for commodity derivative settlements
($2,884)

Lease Operating Expenses, including workover ("LOE").   LOE per Boe for the three months ended December 31, 2020 was $5.15 per Boe, compared to $4.89 per Boe in the third quarter of 2020. The slight increase in LOE per Boe is primarily from the decrease in sequential production as fixed costs are spread over a lower production base.

Production and  Ad Valorem Taxes.  Production and ad valorem taxes were $1.89 per Boe for the three months ended December 31, 2020, representing approximately 6% of revenue excluding revenue from sales of commodities purchased from a third-party and before the impact of derivative settlements.

Gathering, Transportation and Processing. Gathering, transportation and processing for the three months ended December 31, 2020 were $20.7 million as compared to $22.2 million in the third quarter of 2020 In 2020, the Company began reporting gathering, transportation and processing separately due to the assumption of processing agreements in the Carrizo acquisition and certain contract modifications effective January 1, 2020. As such, the Company now records contractual fees associated with gathering, processing, treating and compression, as well as any transportation fees incurred to deliver the product to the purchaser, as gathering, transportation and processing. These fees were historically recorded as a reduction of revenue depending on when control transferred to the purchaser.

Depreciation, Depletion and Amortization ("DD&A").   DD&A for the three months ended December 31, 2020 was $11.00 per Boe compared to $12.17 per Boe in the third quarter of 2020. The decrease in DD&A was primarily driven by the impairment of evaluated oil and gas properties recognized in the third quarter of 2020.

Impairment of Evaluated Oil and Gas Properties. Callon recognized an impairment of evaluated oil and gas properties of $585.8 million for the three months ended December 31, 2020 due primarily to the continued decline in the average realized prices for sales of oil and gas on the first calendar day of each month during the year. For the three months ended September 30, 2020, the Company recognized an impairment of evaluated oil and gas properties of $685.0 million.

General and Administrative Expense ("G&A").   G&A for the three months ended December 31, 2020 and September 30, 2020 was $10.6 million, or $1.22 per Boe, and $8.2 million, or $0.88 per Boe, respectively. G&A, excluding certain non-cash incentive share-based compensation valuation adjustments, ("Adjusted G&A [1] " ) was $8.1 million, or $0.93 per Boe, for the three months ended December 31, 2020 compared to $9.8 million, or $1.04 per Boe, for the third quarter of 2020. The cash component of Adjusted G&A was $7.5 million, or $0.86 per Boe, for the three months ended December 31, 2020 compared to $8.1 million, or $0.87 per Boe, for the third quarter of 2020 primarily as a result of reduced labor expense during the fourth quarter.

The following table reconciles total G&A to Adjusted G&A - cash component, and full cash G&A (in thousands):



Three Months Ended
Year Ended


December 31,2020
September 30,2020
December 31,2019
December 31,2020
Total G&A
$10,614

$8,224

$13,626

$37,187
Change in the fair value of liability share-based awards (non-cash)
(2,500)

1,582

(1,010)

4,110
Adjusted G&A – total
8,114

9,806

12,616

41,297
Restricted stock share-based compensation (non-cash) and other non-recurring expenses
(580)

(1,674)

(2,294)

(7,771)
Adjusted G&A – cash component
$7,534

$8,132

$10,322

$33,526









Capitalized cash G&A
6,465

6,831

8,782

27,606
Full cash G&A
$13,999

$14,963

$19,104

$61,132

Income Tax.  Callon provides for income taxes at a federal statutory rate of 21% adjusted for permanent differences expected to be realized. The Company recorded income tax expense of $6.8 million for the three months ended December 31, 2020, compared to zero income tax expense for the three months ended September 30, 2020 as a result of an increase in the deferred tax assets acquired in the Carrizo Acquisition due to the filing of the final tax returns which provide the underlying tax basis of Carrizo's assets and liabilities and the subsequent valuation allowance against those deferred tax assets.

Loss Available to Common Stockholders.  We recorded a loss available to common stockholders for the three months ended December 31, 2020 of $505.1 million, or $12.71 per diluted share, as compared to a loss available to common stockholders of $680.4 million, or $17.12 per diluted share, for the third quarter of 2020. The losses were primarily due to the impairments of evaluated oil and gas properties of $585.8 million and $685.0 million for the three months ended December 31, 2020 and September 30, 2020, respectively.

Adjusted EBITDA.  Adjusted EBITDA for the fourth quarter of 2020 was $167.8 million as compared to $170.9 million for the third quarter of 2020. The decrease in adjusted EBITDA from the third quarter of 2020 was primarily due to a decrease in production partially offset by an increase in realized prices.

Proved Reserves

DeGolyer and MacNaughton prepared the estimates of Callon's proved reserves as of December 31, 2020. As of December 31, 2020, Callon's estimated net proved reserves were 475.9 MMBoe and included 289.5 MMBbls of oil, 541.6 Bcf of natural gas, and 96.1 MMBbls of NGLs with a standardized measure of discounted future net cash flows of $2.3 billion using average realized prices for sales of oil, natural gas, and NGLs on the first calendar day of each month during the year of $37.44/Bbl for oil, $1.02/Mcf for natural gas, and $11.10/Bbl for NGLs. Utilizing the same reserve database and development schedule, management's internal estimate of PV-10 value [4] at flat forward price realizations of $49.00/Bbl for oil, $2.40/Mcf for natural gas, and $17.65/Bbl for NGLs is just over $4.6 billion. Both of these valuations assume a more moderated pace of development than previously contemplated and have been adjusted as such for less PUD bookings within the normal five-year window.

Oil constituted approximately 61% of the Company's estimated equivalent proved developed reserves as well as the Company's estimated equivalent total proved reserves. The Company added 41.4 MMBoe of new reserves in extensions and discoveries through development efforts in 2020, with a total of 91 gross (86.0 net) wells drilled and 90 gross (81.4 net) wells completed.

The changes in Callon's estimated net proved reserves are as follows:



Total (MBoe)
Proved reserves at December 31, 2019
540,012
Extensions and discoveries
41,407
Revisions to previous estimates
(52,227)
Sales of reserves in place
(16,120)
Production
(37,193)
Proved reserves at December 31, 2020
475,879

2020 Full Year Actuals


Full Year

2020 Actual
Total production (MBoe/d) 101.6
Oil 63%
NGL 19%
Natural gas 18%
Income statement expenses (in millions, except where noted)
LOE, including workovers $194.1
Gathering, transportation and processing $77.3
Production and ad valorem taxes (% of total oil, natural gas, and NGL revenues) 6.4%
Adjusted G&A - cash component (a) $33.5
Adjusted G&A - non-cash component (b) $7.8
Cash interest expense, net $90.4
Capital expenditures (in millions, accrual basis)
Total operational capital (c) $488.6
Capitalized interest and G&A $124.0
Gross operated wells drilled / completed 91 / 90


(a)  Excludes the change in fair value and amortization of share-based incentive awards and other non-recurring expenses.
(b)  Amortization of equity-settled, share based incentive awards and other non-recurring expenses.
(c)  Includes facilities, equipment, seismic, land and other items, excludes capitalized expenses.

2021 Guidance


Full Year

2021 Guidance
Total production (MBoe/d) 90.0 - 92.0
Oil 63%
NGL 19%
Natural gas 18%
Income statement expenses (in millions except where noted)
LOE, including workovers $190.0 - $210.0
Gathering, transportation and processing $70.0 - $80.0
Production and ad valorem taxes (% of total oil, natural gas, and NGL revenues) 6.5%
Adjusted G&A: cash component (a) $35.0 - $45.0
Adjusted G&A: non-cash component (b) $5.0 - $15.0
Cash interest expense, net $80.0 - $90.0
Estimated effective income tax rate 22%
Capital expenditures (in millions, accrual basis)
Total operational capital (c) $430.0
Capitalized interest $95.0 - $105.0
Capitalized G&A $28.0 - $38.0
Gross operated wells drilled / completed 55 - 65 / 90 - 100


(a)  Excludes the change in fair value and amortization of share-based incentive awards and other non-recurring expenses.
(b)  Amortization of equity-settled, share based incentive awards and other non-recurring expenses.
(c)  Includes facilities, equipment, seismic, land and other items, excludes capitalized expenses.

Hedge Portfolio Summary

As of February 19, 2021, Callon had the following outstanding oil, natural gas and NGL derivative contracts:


For the Full Year of
For the Full Year of
Oil contracts (WTI) 2021
2022
Swap contracts



  Total volume (Bbls) 1,827,000



  Weighted average price per Bbl $43.54

$—

Collar contracts



  Total volume (Bbls) 11,202,775

1,355,000

  Weighted average price per Bbl



  Ceiling (short call) $47.80

$60.00

  Floor (long put) $39.95

$45.00

Short call contracts



  Total volume (Bbls) 4,825,300
(a)

  Weighted average price per Bbl $63.62

$—

Short call swaption contracts



  Total volume (Bbls) 455,000
(b) 1,825,000
(b)
  Weighted average price per Bbl $47.00

$52.18






Oil contracts (ICE Brent)



Swap contracts



  Total volume (Bbls) 505,000
(c)

  Weighted average price per Bbl $37.34

$—

Collar contracts



  Total volume (Bbls) 730,000



  Weighted average price per Bbl



  Ceiling (short call) $50.00

$—

  Floor (long put) $45.00

$—






Oil contracts (Midland basis differential)



Swap contracts



  Total volume (Bbls) 3,022,900



  Weighted average price per Bbl $0.26

$—






Oil contracts (Argus Houston MEH)



Swap contracts



  Total volume (Bbls) 450,000



  Weighted average price per Bbl $46.50

$—

Collar contracts



  Total volume (Bbls) 409,500



  Weighted average price per Bbl



  Ceiling (short call) $47.00

$—

  Floor (long put) $41.00

$—



(a)  Premiums from the sale of call options were used to increase the fixed price of certain simultaneously executed price swaps and three-way collars.
(b)  The short call swaption contracts have exercise expiration dates as follows: 455,000 Bbls expire on March 31, 2021 and 1,825,000 Bbls expire on December 31, 2021.
(c)  In January 2021, we paid approximately $3.1 million to terminate 184,000 Bbls of ICE Brent swaps. Additionally, in February 2021, we executed offsetting ICE Brent swaps on 159,300 Bbls, resulting in a locked-in loss of approximately $2.9 million which we will pay as the applicable contracts settle.

 


For the Full Year of
For the Full Year of
Natural gas contracts (Henry Hub) 2021
2022
Swap contracts



  Total volume (MMBtu) 11,123,000



  Weighted average price per MMBtu $2.60

$—

Collar contracts (three-way collars)



  Total volume (MMBtu) 1,350,000



  Weighted average price per MMBtu



  Ceiling (short call) $2.70

$—

  Floor (long put) $2.42

$—

  Floor (short put) $2.00

$—

Collar contracts (two-way collars)



  Total volume (MMBtu) 9,550,000

1,800,000

  Weighted average price per MMBtu



  Ceiling (short call) $3.04

$3.88

  Floor (long put) $2.59

$2.78

Short call contracts



  Total volume (MMBtu) 7,300,000
(a)

  Weighted average price per MMBtu $3.09

$—






Natural gas contracts (Waha basis differential)



Swap contracts



  Total volume (MMBtu) 16,425,000



  Weighted average price per MMBtu ($0.42)

$—



(a)  Premiums from the sale of call options were used to increase the fixed price of certain simultaneously executed price swaps and three-way collars.

 


For the Full Year of
NGL contracts (OPIS Mont Belvieu Purity Ethane) 2021
Swap contracts
  Total volume (Bbls) 1,825,000
  Weighted average price per Bbl $7.62

Adjusted Income and Adjusted EBITDA.   The Company reported loss available to common stockholders of $505.1 million for the three months ended December 31, 2020, or $12.71 per diluted share, and adjusted income of $42.8 million, or $1.00 per diluted share. The following tables reconcile the Company's loss available to common stockholders to adjusted income, and the Company's net loss to adjusted EBITDA:



Three Months Ended
Year Ended


December 31,2020
September 30,2020
December 31,2019
December 31,2020


(In thousands except per share data)
Loss available to common stockholders
($505,071)

($680,384)

($23,543)

($2,533,621)
(Gain) loss on derivatives contracts
125,739

27,038

30,694

27,773
Gain (loss) on commodity derivative settlements, net
(7,938)

(5,540)

(3,353)

95,856
Non-cash stock-based compensation expense (benefit)
2,968

(94)

1,010

2,663
Impairment of evaluated oil and gas properties
585,767

684,956



2,547,241
Merger and integration expense
2,120

2,465

68,420

28,482
Other expense
5,328

3,567



14,625
(Gain) loss on extinguishment of debt
(170,370)



4,881

(170,370)
Tax effect on adjustments above(a)
(114,159)

(149,602)

(21,347)

(534,717)
Change in valuation allowance
118,388

143,152



639,185
Adjusted income
$42,772

$25,558

$56,762

$117,117
Adjusted income per diluted share
$1.00

$0.64

$2.28

$2.86









Basic WASO(b)
39,752

39,746

24,822

39,718
Diluted WASO (GAAP)(b)
39,752

39,746

24,822

39,718
Effective of potentially dilutive instruments(b)
2,892

35

21

1,196
Adjusted Diluted WASO(b)
42,644

39,781

24,843

40,914


(a)  Calculated using the federal statutory rate of 21%.
(b)  All share and per share amounts have been retroactively adjusted for the Company's 1-for-10 reverse stock split effective August 7, 2020.

 



Three Months Ended
Year Ended


December 31,2020
September 30,2020
December 31,2019
December 31,2020


(In thousands)
Net loss
($505,071)

($680,384)

($23,543)

($2,533,621)
(Gain) loss on derivatives contracts
125,739

27,038

30,694

27,773
Gain (loss) on commodity derivative settlements, net
(7,938)

(5,540)

(3,353)

95,856
Non-cash stock-based compensation expense (benefit)
2,968

(94)

3,390

2,663
Impairment of evaluated oil and gas properties
585,767

684,956



2,547,241
Merger and integration expense
2,120

2,465

68,420

28,482
Other expense
5,328

3,567

145

14,625
Income tax expense
6,755



5,857

122,054
Interest expense, net of capitalized amounts
26,486

24,683

689

94,329
Depreciation, depletion and amortization
96,037

114,201

63,198

480,631
(Gain) loss on extinguishment of debt
(170,370)



4,881

(170,370)
Adjusted EBITDA
$167,821

$170,892

$150,378

$709,663

Adjusted Free Cash Flow.  Adjusted free cash flow for the three months ended December 31, 2020 was $24.4 million. The following table reconciles the Company's net cash provided by operating activities to adjusted EBITDA and adjusted free cash flow:



Three Months Ended


December 31,2020
September 30,2020
June 30,2020
March 31,2020
December 31,2019


(In thousands)
Net cash provided by operating activities
$134,578

$135,701

$97,801

$191,695

$137,578
Changes in working capital and other
12,011

14,473

40,078

(32,569)

(55,620)
Changes in accrued hedge settlements
(5,055)

(5,993)

(14,480)

22,513


Cash interest expense, net
24,167

24,246

21,944

20,071


Merger and integration expense
2,120

2,465

8,067

15,830

68,420
Adjusted EBITDA
$167,821

$170,892

$153,410

$217,540

$150,378
Less: Operational capital expenditures (accrual)
87,488

38,408

85,087

277,640

110,021
Less: Capitalized interest
23,015

20,675

20,924

23,985

21,781
Less: Interest expense, net of capitalized amounts
26,486

24,683

22,682

20,478

689
Less: Capitalized cash G&A
6,465

6,831

6,740

7,371

8,780
Adjusted free cash flow
$24,367

$80,295

$17,977

($111,934)

$9,107

Adjusted Discretionary Cash Flow.  Adjusted discretionary cash flow for the three months ended December 31, 2020 was $141.3 million and is reconciled to net cash provided by operating activities in the following table:



Three Months Ended


December 31, 2020
September 30, 2020
December 31, 2019


(In thousands)
Net loss
($505,071)

($680,384)

($23,543)
Adjustments to reconcile net loss to cash provided by operating activities:





Depreciation, depletion and amortization
96,037

114,201

63,198
Impairment of evaluated oil and gas properties
585,767

684,956


Amortization of non-cash debt related items
2,319

437

689
Deferred income tax expense
3,308



5,857
(Gain) loss on derivative contracts
125,739

27,038

30,694
Cash (paid) received for commodity derivative settlements, net
(2,884)

453

(3,353)
Non-cash (gain) loss on early extinguishment of debt
(170,370)



4,881
Non-cash stock-based compensation expense (benefit)
2,968

(94)

3,417
Merger and integration expense
2,120

2,465

68,420
Other, net
1,347

2,099

(126)
Adjusted discretionary cash flow
$141,280

$151,171

$150,134
Changes in working capital
(4,582)

(13,005)

55,864
Merger and integration expense
(2,120)

(2,465)

(68,420)
Net cash provided by operating activities
$134,578

$135,701

$137,578

Adjusted Total Revenue.  Adjusted total revenue for the three months ended December 31, 2020 was $259.0 million and is reconciled to total operating revenues, which excludes revenue from sales of commodities purchased from a third-party, in the following table:



Three Months Ended


December 31, 2020
September 30, 2020
December 31, 2019


(In thousands)
Operating Revenues





Oil
$222,733

$231,654

$183,071
Natural gas
18,561

15,034

10,949
Natural gas liquids
25,668

23,025

2,075
Total operating revenues
$266,962

$269,713

$196,095
Impact of settled derivatives
(7,938)

(5,540)

(3,353)
Adjusted total revenue
$259,024

$264,173

$192,742

PV-10.   PV-10 as of December 31, 2020 is reconciled below to the standardized measure of discounted future net cash flows:



As of December 31, 2020


(In millions)
Standardized measure of discounted future net cash flows
$2,310.4
Add: present value of future income taxes discounted at 10% per annum
$34.6
Total proved reserves - PV-10
$2,345.0
Total proved developed reserves - PV-10
$1,577.3
Total proved undeveloped reserves - PV-10
$767.7

 

Callon Petroleum Company
Consolidated Balance Sheets
(in thousands, except par values and share data)


December 31,

2020
2019
ASSETS


Current assets:


   Cash and cash equivalents $20,236

$13,341
   Accounts receivable, net 133,109

209,463
   Fair value of derivatives 921

26,056
   Other current assets 24,103

19,814
      Total current assets 178,369

268,674
Oil and natural gas properties, full cost accounting method:


      Evaluated properties, net 2,355,710

4,682,994
      Unevaluated properties 1,733,250

1,986,124
      Total oil and natural gas properties, net 4,088,960

6,669,118
Operating lease right-of-use assets 22,526

63,908
Other property and equipment, net 31,640

35,253
Deferred tax asset

115,720
Deferred financing costs 23,643

22,233
Other assets, net 17,730

19,932
   Total assets $4,362,868

$7,194,838
LIABILITIES AND STOCKHOLDERS' EQUITY


Current liabilities:


   Accounts payable and accrued liabilities $345,365

$490,442
   Operating lease liabilities 13,175

42,858
   Fair value of derivatives 97,060

71,197
   Other current liabilities 41,508

47,750
      Total current liabilities 497,108

652,247
Long-term debt 2,969,264

3,186,109
Operating lease liabilities 27,576

37,088
Asset retirement obligations 57,209

48,860
Fair value of derivatives 88,046

32,695
Other long-term liabilities 12,663

14,531
   Total liabilities 3,651,866

3,971,530
Commitments and contingencies


Stockholders' equity:


   Common stock, $0.01 par value, 52,500,000 shares authorized, 39,758,817 and 39,659,001 shares outstanding, respectively (a) 398

3,966
   Capital in excess of par 3,222,959

3,198,076
   Retained earnings (Accumulated deficit) (2,512,355)

21,266
      Total stockholders' equity 711,002

3,223,308
Total liabilities and stockholders' equity $4,362,868

$7,194,838


(a)  All share amounts (except par value) have been retroactively adjusted for the Company's 1-for-10 reverse stock split effective August 7, 2020.

 

Callon Petroleum Company
Consolidated Statements of Operations
(in thousands, except per share data)


Three Months Ended December 31,
For the Year Ended December 31,

2020
2019
2020
2019
Operating Revenues:






Oil $222,733

$183,071

$850,667

$633,107
Natural gas 18,561

10,949

51,866

36,390
Natural gas liquids 25,668

2,075

81,295

2,075
Sales of purchased oil and gas 29,006



49,319


Total operating revenues 295,968

196,095

1,033,147

671,572








Operating Expenses:






Lease operating 45,010

25,316

194,101

91,827
Production and ad valorem taxes 16,487

8,841

62,638

42,651
Gathering, transportation and processing 20,694



77,309


Cost of purchased oil and gas 30,484



51,766


Depreciation, depletion and amortization 96,037

61,367

480,631

240,642
General and administrative 10,614

13,626

37,187

45,331
Impairment of evaluated oil and gas properties 585,767



2,547,241


Merger and integration expenses 2,120

68,420

28,482

74,363
Other operating 2,084

145

10,644

4,100
Total operating expenses 809,297

177,715

3,489,999

498,914
Income (Loss) From Operations (513,329)

18,380

(2,456,852)

172,658








Other (Income) Expenses:






Interest expense, net of capitalized amounts 26,486

689

94,329

2,907
(Gain) loss on derivative contracts 125,739

30,694

27,773

62,109
(Gain) loss on extinguishment of debt (170,370)

4,881

(170,370)

4,881
Other (income) expense 3,132

(198)

2,983

(468)
Total other (income) expense (15,013)

36,066

(45,285)

69,429








Income (Loss) Before Income Taxes (498,316)

(17,686)

(2,411,567)

103,229
Income tax expense (6,755)

(5,857)

(122,054)

(35,301)
Net Income (Loss) ($505,071)

($23,543)

($2,533,621)

$67,928
Preferred stock dividends





(3,997)
Loss on redemption of preferred stock





(8,304)
Income (Loss) Available to Common Stockholders ($505,071)

($23,543)

($2,533,621)

$55,627








Income (Loss) Available to Common Stockholders Per Common Share (a):






Basic ($12.71)

($0.95)

($63.79)

$2.39
Diluted ($12.71)

($0.95)

($63.79)

$2.38








Weighted Average Common Shares Outstanding (a):






Basic 39,752

24,822

39,718

23,313
Diluted 39,752

24,822

39,718

23,340


(a)  All share and per share amounts have been retroactively adjusted for the Company's 1-for-10 reverse stock split effective August 7, 2020.

 

Callon Petroleum Company
Consolidated Statements of Cash Flows
(in thousands)


Three Months Ended December 31,
For the Year Ended December 31,

2020
2019
2020
2019
Cash flows from operating activities:






Net income (loss) ($505,071)

($23,543)

($2,533,621)

$67,928
Adjustments to reconcile net income (loss) to net cash provided by operating activities:






  Depreciation, depletion and amortization 96,037

63,198

480,631

245,936
  Impairment of evaluated oil and gas properties 585,767



2,547,241


  Amortization of non-cash debt related items 2,319

689

3,901

2,907
  Deferred income tax expense 3,308

5,857

118,607

35,301
  (Gain) loss on derivative contracts 125,739

30,694

27,773

62,109
  Cash received (paid) for commodity derivative settlements, net (2,884)

(3,353)

98,870

(3,789)
  (Gain) loss on early extinguishment of debt (170,370)

4,881

(170,370)

4,881
  Non-cash expense related to equity share-based awards 471

1,899

6,773

9,767
  Change in the fair value of liability share-based awards 2,497

1,518

(4,110)

1,624
  Payments for cash-settled restricted stock unit awards



(770)

(1,425)
  Other, net 1,347

(126)

7,857

(90)
  Changes in current assets and liabilities:






    Accounts receivable (20,340)

(52,671)

75,770

(35,071)
    Other current assets 6

1,006

(6,550)

(4,166)
    Accounts payable and accrued liabilities 15,752

96,753

(92,227)

82,290
    Other

10,776



8,114
    Net cash provided by operating activities 134,578

137,578

559,775

476,316
Cash flows from investing activities:






Capital expenditures (109,408)

(137,115)

(677,154)

(640,540)
Acquisitions

(1,478)



(42,266)
Proceeds from sales of assets 29,152

14,465

178,970

294,417
Cash paid for settlements of contingent consideration arrangements, net



(40,000)


Other, net 40



8,301


    Net cash used in investing activities (80,216)

(124,128)

(529,883)

(388,389)
Cash flows from financing activities:






Borrowings on Credit Facility 265,500

1,874,900

5,353,000

2,455,900
Payments on Credit Facility (305,500)

(314,500)

(5,653,000)

(895,500)
Payment to terminate Prior Credit Facility

(475,400)



(475,400)
Repayment of Carrizo's senior secured revolving credit facility

(853,549)



(853,549)
Repayment of Carrizo's preferred stock

(220,399)



(220,399)
Issuance of 9.00% Second Lien Senior Secured Notes due 2025



300,000


Discount on the issuance of 9.00% Second Lien Senior Secured Notes due 2025



(35,270)


Issuance of September 2020 Warrants



23,909


Payment of preferred stock dividends





(3,997)
Payment of deferred financing costs and debt exchange costs (4,499)

(22,449)

(10,811)

(22,480)
Tax withholdings related to restricted stock units (14)

(21)

(509)

(2,195)
Redemption of preferred stock





(73,017)
Other, net (113)



(316)


    Net cash used in financing activities (44,626)

(11,418)

(22,997)

(90,637)
Net change in cash and cash equivalents 9,736

2,032

6,895

(2,710)
  Balance, beginning of period 10,500

11,309

13,341

16,051
  Balance, end of period $20,236

$13,341

$20,236

$13,341

Non-GAAP Financial Measures

This news release refers to non-GAAP financial measures such as  "adjusted free cash flow," "adjusted discretionary cash flow," "adjusted G&A," "full cash G&A," "adjusted income," "adjusted income per diluted share," "adjusted EBITDA", "adjusted total revenue", and "PV-10."  These measures, detailed below, are provided in addition to, and not as an alternative for, and should be read in conjunction with, the information contained in our financial statements prepared in accordance with GAAP (including the notes), included in our filings with the U.S. Securities and Exchange Commission (the "SEC") and posted on our website.

  • Adjusted free cash flow is a supplemental non-GAAP measure that is defined by the Company as adjusted EBITDA less operational capital, capitalized interest, net interest expense and capitalized cash G&A (which excludes capitalized expense related to share-based awards). We believe adjusted free cash flow is a comparable metric against other companies in the industry and is a widely accepted financial indicator of an oil and natural gas company's ability to generate cash for the use of internally funding their capital development program and to service or incur debt. Adjusted free cash flow is not a measure of a company's financial performance under GAAP and should not be considered as an alternative to net cash provided by operating activities, or as a measure of liquidity, or as an alternative to net income (loss).

  • Adjusted discretionary cash flow is a supplemental non-GAAP measure that Callon believes is a comparable metric against other companies in the industry and is a widely accepted financial indicator of an oil and natural gas company's ability to generate cash for the use of internally funding their capital development program and to service or incur debt. Adjusted discretionary cash flow is defined by Callon as net cash provided by operating activities before changes in working capital and merger and integration expenses. Callon has included this information because changes in operating assets and liabilities relate to the timing of cash receipts and disbursements, which the Company may not control and the cash flow effect may not be reflected the period in which the operating activities occurred. Adjusted discretionary cash flow is not a measure of a company's financial performance under GAAP and should not be considered as an alternative to net cash provided by operating activities, or as a measure of liquidity, or as an alternative to net income (loss).

  • Adjusted G&A is a supplemental non-GAAP financial measure that excludes certain non-recurring expenses and non-cash valuation adjustments related to incentive compensation plans. Callon believes that the non-GAAP measure of adjusted G&A is useful to investors because it provides a meaningful measure of our recurring G&A expense and provides for greater comparability period-over-period. See the reconciliation provided above for further details.

  • Full cash G&A is a supplemental non-GAAP financial measure that Callon defines as adjusted G&A – cash component plus capitalized G&A excluding capitalized expense related to share-based awards. Callon believes that the non-GAAP measure of full cash G&A is useful because it provides users with a meaningful measure of our total recurring cash G&A costs, whether expensed or capitalized, and provides for greater comparability on a period-over-period basis. See the reconciliation provided above for further details.

  • Adjusted income and adjusted income per diluted share are supplemental non-GAAP measures that Callon believes are useful to investors because they provide readers with a meaningful measure of our profitability before recording certain items whose timing or amount cannot be reasonably determined. These measures exclude the net of tax effects of these items and non-cash valuation adjustments, which are detailed in the reconciliation provided. Adjusted income and adjusted income per diluted share are not measures of financial performance under GAAP. Accordingly, it should not be considered as a substitute for net income (loss), operating income (loss), or other income data prepared in accordance with GAAP. However, the Company believes that adjusted income and adjusted income per diluted share provide additional information with respect to our performance. Because adjusted income and adjusted income per diluted share exclude some, but not all, items that affect net income (loss) and may vary among companies, the adjusted income and adjusted income per diluted share presented above may not be comparable to similarly titled measures of other companies.

  • Adjusted diluted weighted average common shares outstanding ("Adjusted Diluted WASO") is a non-GAAP financial measure which includes the effect of potentially dilutive instruments that, under certain circumstances described below, are excluded from diluted weighted average common shares outstanding ("Diluted WASO"), the most directly comparable GAAP financial measure. When a loss available to common stockholders exists, all potentially dilutive instruments are anti-dilutive to the loss available to common stockholders per common share and therefore excluded from the computation of Diluted WASO. The effect of potentially dilutive instruments are included in the computation of Adjusted Diluted WASO for purposes of computing adjusted income per diluted share.

  • Callon calculates adjusted earnings before interest, income taxes, depreciation, depletion and amortization ("Adjusted EBITDA") as net income (loss) before interest expense, income tax expense (benefit), depreciation, depletion and amortization, (gains) losses on derivative instruments excluding net settled derivative instruments, impairment of evaluated oil and gas properties, non-cash stock-based compensation expense, merger and integration expense, (gain) loss on extinguishment of debt, and other operating expenses. Adjusted EBITDA is not a measure of financial performance under GAAP. Accordingly, it should not be considered as a substitute for net income (loss), operating income (loss), cash flow provided by operating activities or other income or cash flow data prepared in accordance with GAAP. However, the Company believes that adjusted EBITDA provides additional information with respect to our performance or ability to meet our future debt service, capital expenditures and working capital requirements. Because adjusted EBITDA excludes some, but not all, items that affect net income (loss) and may vary among companies, the adjusted EBITDA presented above may not be comparable to similarly titled measures of other companies.

  • Callon believes that the non-GAAP measure of adjusted total revenue is useful to investors because it provides readers with a revenue value more comparable to other companies who engage in price risk management activities through the use of commodity derivative instruments and reflects the results of derivative settlements with expected cash flow impacts within total revenues. See the reconciliation provided above for further details.

  • Callon believes that the presentation of pre-tax PV-10 value is relevant and useful to its investors because it presents the discounted future net cash flows attributable to reserves prior to taking into account future corporate income taxes and the Company's current tax structure. The Company further believes investors and creditors use pre-tax PV-10 values as a basis for comparison of the relative size and value of its reserves as compared with other companies. The GAAP financial measure most directly comparable to pre-tax PV-10 is the standardized measure of discounted future net cash flows. Pre-tax PV-10 is calculated using the standardized measure of discounted future net cash flows before deducting future income taxes, discounted at 10 percent.

Earnings Call Information

The Company will host a conference call on Thursday, February 25, 2021, to discuss fourth quarter 2020 financial and operating results, 2021 outlook, and the durability of our business under various commodity price scenarios.

Please join Callon Petroleum Company via the Internet for a webcast of the conference call:

Date/Time: Thursday, February 25, 2021, at 8:00 a.m. Central Time (9:00 a.m. Eastern Time)
Webcast: Select "News and Events" under the "Investors" section of the Company's website: www.callon.com.

An archive of the conference call webcast will also be available at www.callon.com under the "Investors" section of the website.

About Callon Petroleum

Callon Petroleum Company is an independent oil and natural gas company focused on the acquisition, exploration and development of high-quality assets in the leading oil plays of South and West Texas.

Cautionary Statement Regarding Forward Looking Statements

This news release contains 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. Forward-looking statements include all statements regarding wells anticipated to be drilled and placed on production; future levels of development activity and associated production, capital expenditures and cash flow expectations; the Company's 2021 production expense guidance and capital expenditure guidance; estimated reserve quantities and the present value thereof; and the implementation of the Company's business plans and strategy, as well as statements including the words "believe," "expect," "plans", "may", "will", "should", "could" and words of similar meaning. These statements reflect the Company's current views with respect to future events and financial performance based on management's experience and perception of historical trends, current conditions, anticipated future developments and other factors believed to be appropriate. No assurances can be given, however, that these events will occur or that these projections will be achieved, and actual results could differ materially from those projected as a result of certain factors. Any forward-looking statement speaks only as of the date on which such statement is made and the Company undertakes no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law. Some of the factors which could affect our future results and could cause results to differ materially from those expressed in our forward-looking statements include the volatility of oil and natural gas prices; changes in the supply of and demand for oil and natural gas, including as a result of the COVID-19 pandemic and various governmental actions taken to mitigate its impact or actions by, or disputes among, members of OPEC and other oil and natural gas producing countries, such as Russia, with respect to production levels or other matters related to the price of oil; our ability to drill and complete wells, operational, regulatory and environment risks; the cost and availability of equipment and labor; our ability to finance our activities;  and other risks more fully discussed in our filings with the SEC, including our most recent Annual Reports on Form 10-K and subsequent Quarterly Reports on Form 10-Q, available on our website or the SEC's website at  www.sec.gov .

Contact information

Mark Brewer Director of Investor Relations Callon Petroleum Company ir@callon.com 1-281-589-5200

1) See "Non-GAAP Financial Measures" included within this release for related disclosures.
2) All references to 2019 pro forma figures assume full year Callon and Carrizo combined financials
3) Callon defines "reinvestment rate" as (Accrued Operational Capital Expenditures) / (Adjusted Discretionary Cash Flow - Capitalized Expenses)
4) Management's internal estimate of PV-10 value at flat forward prices set forth above is provided to illustrate reserve sensitivities to expectations of commodity prices and do not comply with SEC pricing assumptions. Actual future prices may vary significantly from the flat forward prices used in management's internal estimate of PV-10; therefore, actual revenue and value generated may be more or less than the PV-10 estimate.

 

Cision
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SOURCE Callon Petroleum Company

COMTEX_381669752/2454/2021-02-24T16:10:24

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/zigman2/quotes/201917664/composite
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$ 39.79
-1.33 -3.23%
Volume: 4.77M
May 10, 2021 4:00p
P/E Ratio
N/A
Dividend Yield
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Rev. per Employee
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