Oklahoma
|
73-1395733
|
|||
(State or other jurisdiction of incorporation or organization)
|
(I.R.S. Employer Identification No.)
|
|||
6100 North Western Avenue,
|
Oklahoma City,
|
Oklahoma
|
73118
|
|
(Address of principal executive offices)
|
(Zip Code)
|
|||
|
|
(405)
|
848-8000
|
|
(Registrant’s telephone number, including area code)
|
|
Page
|
|||
|
|
|||
|
||||
|
||||
|
|
|||
|
|
|||
|
|
|
|
|
•
|
our ability to comply with the covenants under our revolving credit facility and other indebtedness;
|
•
|
the volatility of oil, natural gas and NGL prices, which are affected by general economic and business conditions, as well as increased demand for (and availability of) alternative fuels and electric vehicles;
|
•
|
uncertainties inherent in estimating quantities of oil, natural gas and NGL reserves and projecting future rates of production and the amount and timing of development expenditures;
|
•
|
our ability to replace reserves and sustain production;
|
•
|
drilling and operating risks and resulting liabilities;
|
•
|
our ability to generate profits or achieve targeted results in drilling and well operations;
|
•
|
the limitations our level of indebtedness may have on our financial flexibility;
|
•
|
our inability to access the capital markets on favorable terms;
|
•
|
the availability of cash flows from operations and other funds to finance reserve replacement costs or satisfy our debt obligations;
|
•
|
adverse developments or losses from pending or future litigation and regulatory proceedings, including royalty claims;
|
•
|
legislative and regulatory initiatives addressing environmental concerns, including initiatives addressing the impact of global climate change or further regulating hydraulic fracturing, methane emissions, flaring or water disposal;
|
•
|
terrorist activities and/or cyber-attacks adversely impacting our operations;
|
•
|
effects of acquisitions and dispositions, including our acquisition of WildHorse and our ability to realize related synergies and cost savings;
|
•
|
effects of purchase price adjustments and indemnity obligations; and
|
•
|
other factors that are described under Risk Factors in Item 1A of this Form 10-K.
|
Item 1.
|
Business
|
|
|
2019
|
|
2018
|
|
2017
|
||||||||||||||||||||||||||||||
|
|
Gross
|
|
%
|
|
Net
|
|
%
|
|
Gross
|
|
%
|
|
Net
|
|
%
|
|
Gross
|
|
%
|
|
Net
|
|
%
|
||||||||||||
Development:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Productive
|
|
414
|
|
|
100
|
|
|
271
|
|
|
100
|
|
|
363
|
|
|
99
|
|
|
227
|
|
|
99
|
|
|
462
|
|
|
99
|
|
|
292
|
|
|
99
|
|
Dry
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
2
|
|
|
1
|
|
|
1
|
|
|
1
|
|
|
4
|
|
|
1
|
|
|
2
|
|
|
1
|
|
Total
|
|
414
|
|
|
100
|
|
|
271
|
|
|
100
|
|
|
365
|
|
|
100
|
|
|
228
|
|
|
100
|
|
|
466
|
|
|
100
|
|
|
294
|
|
|
100
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Exploratory:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Productive
|
|
1
|
|
|
20
|
|
|
1
|
|
|
20
|
|
|
10
|
|
|
83
|
|
|
9
|
|
|
82
|
|
|
2
|
|
|
100
|
|
|
2
|
|
|
100
|
|
Dry
|
|
4
|
|
|
80
|
|
|
4
|
|
|
80
|
|
|
2
|
|
|
17
|
|
|
2
|
|
|
18
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
Total
|
|
5
|
|
|
100
|
|
|
5
|
|
|
100
|
|
|
12
|
|
|
100
|
|
|
11
|
|
|
100
|
|
|
2
|
|
|
100
|
|
|
2
|
|
|
100
|
|
|
|
2019
|
|
2018
|
|
2017
|
||||||||||||
|
|
Gross Wells
|
|
Net Wells
|
|
Gross Wells
|
|
Net Wells
|
|
Gross Wells
|
|
Net Wells
|
||||||
Marcellus
|
|
44
|
|
|
22
|
|
|
52
|
|
|
23
|
|
|
43
|
|
|
21
|
|
Haynesville
|
|
22
|
|
|
16
|
|
|
30
|
|
|
21
|
|
|
37
|
|
|
34
|
|
Eagle Ford
|
|
150
|
|
|
85
|
|
|
162
|
|
|
98
|
|
|
180
|
|
|
106
|
|
Brazos Valley
|
|
83
|
|
|
79
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
Powder River Basin
|
|
75
|
|
|
57
|
|
|
41
|
|
|
34
|
|
|
25
|
|
|
21
|
|
Mid-Continent
|
|
40
|
|
|
12
|
|
|
52
|
|
|
32
|
|
|
114
|
|
|
58
|
|
Utica
|
|
—
|
|
|
—
|
|
|
40
|
|
|
31
|
|
|
69
|
|
|
56
|
|
Other
|
|
5
|
|
|
5
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
Total
|
|
419
|
|
|
276
|
|
|
377
|
|
|
239
|
|
|
468
|
|
|
296
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
Net Production:
|
|
|
|
|
|
|
||||||
Oil (mmbbl)
|
|
43
|
|
|
33
|
|
|
33
|
|
|||
Natural gas (bcf)
|
|
728
|
|
|
832
|
|
|
878
|
|
|||
NGL (mmbbl)
|
|
12
|
|
|
19
|
|
|
21
|
|
|||
Oil equivalent (mmboe)
|
|
177
|
|
|
190
|
|
|
200
|
|
|||
|
|
|
|
|
|
|
||||||
Average Sales Price of Production:
|
|
|
|
|
|
|
||||||
Oil ($ per bbl)
|
|
$
|
59.16
|
|
|
$
|
67.25
|
|
|
$
|
51.03
|
|
Natural gas ($ per mcf)
|
|
$
|
2.45
|
|
|
$
|
2.99
|
|
|
$
|
2.76
|
|
NGL ($ per bbl)
|
|
$
|
15.62
|
|
|
$
|
26.50
|
|
|
$
|
23.18
|
|
Oil equivalent ($ per boe)
|
|
$
|
25.57
|
|
|
$
|
27.27
|
|
|
$
|
22.88
|
|
|
|
|
|
|
|
|
||||||
Average Sales Price (including realized gains (losses) on derivatives):
|
|
|
|
|
||||||||
Oil ($ per bbl)
|
|
$
|
60.00
|
|
|
$
|
57.42
|
|
|
$
|
53.19
|
|
Natural gas ($ per mcf)
|
|
$
|
2.60
|
|
|
$
|
3.00
|
|
|
$
|
2.75
|
|
NGL ($ per bbl)
|
|
$
|
15.62
|
|
|
$
|
25.84
|
|
|
$
|
22.98
|
|
Oil equivalent ($ per boe)
|
|
$
|
26.42
|
|
|
$
|
25.56
|
|
|
$
|
23.17
|
|
|
|
|
|
|
|
|
||||||
Expenses ($ per boe):
|
|
|
|
|
|
|
||||||
Oil, natural gas and NGL production
|
|
$
|
2.94
|
|
|
$
|
2.50
|
|
|
$
|
2.59
|
|
Oil, natural gas and NGL gathering, processing and transportation
|
|
$
|
6.13
|
|
|
$
|
7.35
|
|
|
$
|
7.36
|
|
|
|
December 31, 2019
|
||||||||||
|
|
Oil
|
|
Natural Gas
|
|
NGL
|
|
Total
|
||||
|
|
(mmbbl)
|
|
(bcf)
|
|
(mmbbl)
|
|
(mmboe)
|
||||
Proved developed
|
|
201
|
|
|
3,377
|
|
|
82
|
|
|
846
|
|
Proved undeveloped
|
|
157
|
|
|
3,189
|
|
|
38
|
|
|
726
|
|
Total proved(a)
|
|
358
|
|
|
6,566
|
|
|
120
|
|
|
1,572
|
|
|
|
Proved
Developed
|
|
Proved
Undeveloped
|
|
Total
Proved
|
||||||
|
|
($ in millions)
|
||||||||||
Estimated future net revenue(b)
|
|
$
|
10,488
|
|
|
$
|
6,656
|
|
|
$
|
17,144
|
|
Present value of estimated future net revenue (PV-10)(b)
|
|
$
|
6,341
|
|
|
$
|
2,674
|
|
|
$
|
9,015
|
|
Standardized measure(b)
|
|
$
|
9,000
|
|
(a)
|
Marcellus, Eagle Ford, Haynesville and Brazos Valley accounted for approximately 42%, 19%, 18%, and 14% respectively, of our estimated proved reserves by volume as of December 31, 2019.
|
(b)
|
Estimated future net revenue represents the estimated future revenue to be generated from the production of proved reserves, net of estimated production and future development costs, using pricing differentials and costs under existing economic conditions as of December 31, 2019, and assuming commodity prices as set forth below. For the purpose of determining prices used in our reserve reports, we used the unweighted arithmetic average of the prices on the first day of each month within the 12-month period ended December 31, 2019. The prices used in our PV-10 measure were $55.69 of oil and $2.58 of natural gas, before basis differential adjustments. These prices should not be interpreted as a prediction of future prices, nor do they reflect the value of our commodity derivative instruments in place as of December 31, 2019. The amounts shown do not give effect to non-property-related expenses, such as corporate general and administrative expenses and debt service, or to depreciation, depletion and amortization. The present value of estimated future net revenue typically differs from the standardized measure because the former does not include the effects of estimated future income tax expense of $15 million as of December 31, 2019.
|
|
|
Total
|
|
|
|
(mmboe)
|
|
Proved undeveloped reserves, beginning of period
|
|
700
|
|
Extensions and discoveries
|
|
185
|
|
Revisions of previous estimates
|
|
(128
|
)
|
Developed
|
|
(167
|
)
|
Purchase of reserves-in-place
|
|
136
|
|
Proved undeveloped reserves, end of period
|
|
726
|
|
•
|
over 17 years of practical experience in the oil and gas industry, with approximately 15 years in reservoir engineering;
|
•
|
Bachelor of Science degree in Geology and Environmental Sciences;
|
•
|
Master’s Degree in Petroleum and Natural Gas Engineering;
|
•
|
Executive MBA; and
|
•
|
member in good standing of the Society of Petroleum Engineers.
|
•
|
We follow comprehensive SEC-compliant internal policies to estimate and report proved reserves. Reserve estimates are made by experienced reservoir engineers or under their direct supervision. All material changes are reviewed and approved by Corporate Reserves Engineers.
|
•
|
The Corporate Reserves Department reviews our proved reserves at the close of each quarter.
|
•
|
Each quarter, Reservoir Managers, the Director – Corporate Reserves, the Vice Presidents of our business units, the Vice President of Corporate and Strategic Planning and the Executive Vice President – Exploration and Production review all significant reserves changes and all new proved undeveloped reserves additions.
|
•
|
The Corporate Reserves Department reports independently of our operations.
|
•
|
The five-year PUD development plan is reviewed and approved annually by the Director – Corporate Reserves and the Vice President of Corporate and Strategic Planning.
|
•
|
over 30 years of practical experience in the estimation and evaluation of reserves;
|
•
|
registered professional geologist license in the Commonwealth of Pennsylvania;
|
•
|
member in good standing of the Society of Petroleum Engineers and the Society of Petroleum Evaluation Engineers; and
|
•
|
Bachelor of Science degree in Geological Sciences.
|
|
|
Developed Leasehold
|
|
Undeveloped Leasehold
|
|
Fee Minerals
|
|
Total
|
||||||||||||||||
|
|
Gross
Acres
|
|
Net
Acres
|
|
Gross
Acres
|
|
Net
Acres
|
|
Gross
Acres
|
|
Net
Acres
|
|
Gross
Acres
|
|
Net
Acres
|
||||||||
|
|
(in thousands)
|
||||||||||||||||||||||
Marcellus
|
|
547
|
|
|
350
|
|
|
253
|
|
|
172
|
|
|
16
|
|
|
16
|
|
|
816
|
|
|
538
|
|
Haynesville
|
|
293
|
|
|
263
|
|
|
36
|
|
|
29
|
|
|
1
|
|
|
1
|
|
|
330
|
|
|
293
|
|
Eagle Ford
|
|
310
|
|
|
186
|
|
|
68
|
|
|
46
|
|
|
—
|
|
|
—
|
|
|
378
|
|
|
232
|
|
Brazos Valley
|
|
411
|
|
|
321
|
|
|
302
|
|
|
156
|
|
|
—
|
|
|
—
|
|
|
713
|
|
|
477
|
|
Powder River Basin
|
|
96
|
|
|
77
|
|
|
166
|
|
|
128
|
|
|
1
|
|
|
1
|
|
|
263
|
|
|
206
|
|
Mid-Continent
|
|
900
|
|
|
582
|
|
|
211
|
|
|
138
|
|
|
17
|
|
|
16
|
|
|
1,128
|
|
|
736
|
|
Other(a)
|
|
167
|
|
|
132
|
|
|
967
|
|
|
912
|
|
|
431
|
|
|
427
|
|
|
1,565
|
|
|
1,471
|
|
Total
|
|
2,724
|
|
|
1,911
|
|
|
2,003
|
|
|
1,581
|
|
|
466
|
|
|
461
|
|
|
5,193
|
|
|
3,953
|
|
(a)
|
Includes 1.3 million net acres retained in the 2016 divestiture of our Devonian Shale assets, in which we retained all rights below the base of the Kope formation.
|
|
|
Acres Expiring
|
||||
|
|
Gross
Acres
|
|
Net
Acres
|
||
|
|
(in thousands)
|
||||
Years Ending December 31:
|
|
|
|
|
||
2020
|
|
83
|
|
|
79
|
|
2021
|
|
62
|
|
|
54
|
|
2022
|
|
28
|
|
|
28
|
|
After 2022
|
|
88
|
|
|
86
|
|
Held-by-production(a)
|
|
1,742
|
|
|
1,334
|
|
Total
|
|
2,003
|
|
|
1,581
|
|
(a)
|
Held-by-production acres will remain in force as production continues on the subject leases.
|
•
|
reporting of workplace injuries and illnesses;
|
•
|
industrial hygiene monitoring;
|
•
|
worker protection and workplace safety;
|
•
|
approval or permits to drill and to conduct operations;
|
•
|
provision of financial assurances (such as bonds) covering drilling and well operations;
|
•
|
calculation and disbursement of royalty payments and production taxes;
|
•
|
seismic operations/data;
|
•
|
hydraulic fracturing;
|
•
|
location, drilling, cementing and casing of wells;
|
•
|
well design and construction of pad and equipment;
|
•
|
construction and operations activities in sensitive areas, such as wetlands, coastal regions or areas that contain endangered or threatened species, their habitats, or sites of cultural significance;
|
•
|
method of well completion and hydraulic fracturing;
|
•
|
water withdrawal;
|
•
|
well production and operations, including processing and gathering systems;
|
•
|
emergency response, contingency plans and spill prevention plans;
|
•
|
emissions and discharges permitting;
|
•
|
climate change;
|
•
|
use, transportation, storage and disposal of fluids and materials incidental to oil and gas operations;
|
•
|
surface usage, maintenance, monitoring and the restoration of properties associated with well pads, pipelines, impoundments and access roads;
|
•
|
plugging and abandoning of wells; and
|
•
|
transportation of production.
|
ITEM 1A.
|
Risk Factors
|
•
|
domestic and worldwide supplies of oil, natural gas and NGL, including U.S. inventories of oil and natural gas reserves;
|
•
|
weather conditions;
|
•
|
changes in the level of consumer and industrial demand, including impacts from global or national health epidemics and concerns, such as the recent coronavirus;
|
•
|
the price and availability of alternative fuels;
|
•
|
technological advances affecting energy consumption;
|
•
|
the effectiveness of worldwide conservation measures;
|
•
|
the availability, proximity and capacity of pipelines, other transportation facilities and processing facilities;
|
•
|
the level and effect of trading in commodity futures markets, including by commodity price speculators and others;
|
•
|
U.S. exports of oil, natural gas, liquefied natural gas and NGL;
|
•
|
the price and level of foreign imports;
|
•
|
the nature and extent of domestic and foreign governmental regulations and taxes;
|
•
|
the ability of the members of the Organization of Petroleum Exporting Countries and others to agree to and maintain oil price and production controls;
|
•
|
increased use of competing energy products, including alternative energy sources;
|
•
|
political instability or armed conflict in oil and natural gas producing regions;
|
•
|
acts of terrorism; and
|
•
|
domestic and global economic conditions.
|
•
|
require us to dedicate a substantial portion of our cash flow from operations to service our existing debt obligations and could limit our flexibility in planning for or reacting to changes in our business and the industry in which we operate;
|
•
|
increase our vulnerability to the cyclical nature of our business, economic downturns or other adverse developments in our business;
|
•
|
could limit our ability to access capital markets, refinance our existing indebtedness, raise capital on favorable terms, or obtain additional financing for working capital, capital expenditures, acquisitions, debt service requirements, execution of our business strategy, or for other purposes;
|
•
|
expose us to the risk of increased interest rates as certain of our borrowings, including borrowings under the Chesapeake revolving credit facility, bear interest at floating rates;
|
•
|
place restrictions on our ability to obtain additional financing, make investments, lease equipment, sell assets and engage in business combinations;
|
•
|
place us at a competitive disadvantage relative to competitors with lower levels of indebtedness in relation to their overall size, or those that have less restrictive terms governing their indebtedness, thereby enabling competitors to take advantage of opportunities that our indebtedness may prevent us from pursuing;
|
•
|
limit management’s discretion in operating our business; and
|
•
|
increase our cost of borrowing.
|
•
|
refinancing or restructuring all or a portion of our debt;
|
•
|
seeking alternative financing or additional capital investment;
|
•
|
selling strategic assets;
|
•
|
reducing or delaying capital investments, including by curtailing our drilling program; or
|
•
|
revising or delaying our strategic plans.
|
•
|
incur additional indebtedness;
|
•
|
make investments or loans;
|
•
|
create liens;
|
•
|
consummate mergers and similar fundamental changes;
|
•
|
make restricted payments;
|
•
|
make investments in unrestricted subsidiaries;
|
•
|
enter into transactions with affiliates; and
|
•
|
use the proceeds of asset sales.
|
•
|
limit our ability to plan for, or react to, market conditions, to meet capital needs or otherwise to restrict our activities or business plan; and
|
•
|
adversely affect our ability to finance our operations, enter into acquisitions or divestitures to engage in other business activities that would be in our interest.
|
•
|
unexpected drilling conditions, pressure conditions or irregularities in reservoir formations;
|
•
|
equipment failures or accidents;
|
•
|
fires, explosions, blowouts, cratering or loss of well control, such as the January 30, 2020 well control incident at a wellsite located in Burleson County, Texas, causing the deaths of three of our contractors’ employees and injuring a fourth;
|
•
|
the mishandling or underground migration of fluids and chemicals;
|
•
|
adverse weather conditions and natural disasters, such as tornadoes, earthquakes, hurricanes and extreme temperatures;
|
•
|
issues with title or in receiving governmental permits or approvals;
|
•
|
restricted takeaway capacity for our production, including due to inadequate midstream infrastructure or constrained downstream markets;
|
•
|
environmental hazards or liabilities;
|
•
|
restrictions in access to, or disposal of, water used or produced in drilling and completion operations;
|
•
|
shortages or delays in the availability of services or delivery of equipment; and
|
•
|
unexpected or unforeseen changes in regulatory policy, and political or public opinion.
|
•
|
any acquisition would be successfully integrated into our operations and internal controls;
|
•
|
the due diligence conducted prior to an acquisition would uncover situations that could result in financial or legal exposure, such as title defects and potential environmental and other liabilities;
|
•
|
post-closing purchase price adjustments will be realized in our favor;
|
•
|
our assumptions about, among other things, reserves, estimated production, revenues, capital expenditures, operating, operating expenses and costs would be accurate;
|
•
|
any investment, acquisition, disposition or integration would not divert management resources from the operation of our business; and
|
•
|
any investment, acquisition, or disposition or integration would not have a material adverse effect on our financial condition, results of operations, cash flows or reserves.
|
ITEM 1B.
|
Unresolved Staff Comments
|
ITEM 2.
|
Properties
|
ITEM 3.
|
Legal Proceedings
|
ITEM 4.
|
Mine Safety Disclosures
|
ITEM 5.
|
Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
|
Period
|
|
Total
Number
of Shares
Purchased(a)
|
|
Average
Price
Paid
Per
Share(a) |
|
Total Number
of Shares
Purchased as
Part of
Publicly
Announced
Plans or
Programs
|
|
Maximum
Approximate
Dollar Value
of Shares
That May Yet
Be Purchased
Under
the Plans
or Programs
|
||||||
|
|
|
|
|
|
|
|
($ in millions)
|
||||||
October 1, 2019 through October 31, 2019
|
|
44,323
|
|
|
$
|
1.44
|
|
|
—
|
|
|
$
|
—
|
|
November 1, 2019 through November 30, 2019
|
|
—
|
|
|
$
|
—
|
|
|
—
|
|
|
$
|
—
|
|
December 1, 2019 through December 31, 2019
|
|
—
|
|
|
$
|
—
|
|
|
—
|
|
|
$
|
—
|
|
Total
|
|
44,323
|
|
|
$
|
—
|
|
|
—
|
|
|
|
(a)
|
Includes shares of common stock purchased on behalf of our deferred compensation plan.
|
ITEM 6.
|
Selected Financial Data
|
|
|
Years Ended December 31,
|
||||||||||||||||||
|
|
2019
|
|
2018
|
|
2017
|
|
2016
|
|
2015
|
||||||||||
|
|
($ in millions, except per share data)
|
||||||||||||||||||
STATEMENT OF OPERATIONS DATA:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Total revenues
|
|
$
|
8,595
|
|
|
$
|
10,030
|
|
|
$
|
10,039
|
|
|
$
|
8,705
|
|
|
$
|
13,794
|
|
Net income (loss) available to common stockholders(a)
|
|
$
|
(416
|
)
|
|
$
|
133
|
|
|
$
|
(631
|
)
|
|
$
|
(4,018
|
)
|
|
$
|
(11,383
|
)
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
EARNINGS (LOSS) PER COMMON SHARE:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Basic
|
|
$
|
(0.25
|
)
|
|
$
|
0.15
|
|
|
$
|
(0.70
|
)
|
|
$
|
(5.26
|
)
|
|
$
|
(17.18
|
)
|
Diluted
|
|
$
|
(0.25
|
)
|
|
$
|
0.15
|
|
|
$
|
(0.70
|
)
|
|
$
|
(5.26
|
)
|
|
$
|
(17.18
|
)
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
CASH DIVIDEND DECLARED PER COMMON SHARE
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
0.0875
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
BALANCE SHEET DATA (AT END OF PERIOD):
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Total assets
|
|
$
|
16,193
|
|
|
$
|
12,735
|
|
|
$
|
14,925
|
|
|
$
|
17,048
|
|
|
$
|
21,432
|
|
Long-term debt, net of current maturities
|
|
$
|
9,073
|
|
|
$
|
7,341
|
|
|
$
|
9,921
|
|
|
$
|
9,938
|
|
|
$
|
10,311
|
|
Total equity
|
|
$
|
4,401
|
|
|
$
|
2,133
|
|
|
$
|
1,943
|
|
|
$
|
2,565
|
|
|
$
|
5,256
|
|
(a)
|
Includes $11 million, $131 million, $814 million, $563 million and $11.590 billion of impairments of oil and gas properties and other fixed assets for the years ended December 31, 2019, 2018, 2017, 2016 and 2015, respectively.
|
ITEM 7.
|
Management’s Discussion and Analysis of Financial Condition and Results of Operations
|
•
|
acquired WildHorse, an oil and gas company with operations in the Eagle Ford Shale and Austin Chalk formations in southeast Texas, for approximately 717.4 million shares of our common stock and $381 million in cash, and the assumption of WildHorse’s debt of $1.4 billion as of February 1, 2019. We anticipate the acquisition to materially increase our oil production and enhance our oil production mix as well as significantly reduce costs due to operational synergies that we believe the combined company will achieve. We achieved $250 million of cost savings in 2019 and we expect that the WildHorse Merger will provide substantial cost savings with $200 million to $280 million in projected average annual savings, totaling $1 billion to $1.5 billion by 2023, due to operational and capital efficiencies as a result of Chesapeake’s significant expertise with unconventional assets and technical and operational excellence;
|
•
|
entered into a secured 4.5-year term loan facility for $1.5 billion to finance a tender offer for unsecured notes issued by Brazos Valley Longhorn and Brazos Valley Longhorn Finance Corp., each a wholly owned subsidiary of Chesapeake, and to fund the retirement of Brazos Valley Longhorn’s secured revolving credit facility;
|
•
|
exchanged new 11.5% Senior Secured Second Lien Notes due 2025 for 8.00% Senior Notes due 2027, 8.00% Senior Notes due 2026, 8.00% Senior Notes due 2025, 7.50% Senior Notes due 2026 and 7.00% Senior Notes due 2024. Also, we issued an additional $120 million of 11.5% Senior Secured Second Lien Notes due 2025 pursuant to a private offering, at 89.75% of par. These transactions resulted in the removal of approximately $900 million principal amount of debt from the company’s balance sheet.
|
•
|
privately negotiated exchanges of approximately $507 million principal amount of our outstanding senior notes for 235,563,519 shares of common stock and $186 million principal amount of our outstanding convertible senior notes for 73,389,094 shares of common stock, reducing annual interest payments;
|
•
|
exchanged 40,000 shares of our 5.75% (Series A) Cumulative Convertible Preferred Stock for 10,367,950 shares of common stock, reducing annual preferred stock dividend payments;
|
•
|
extended our debt maturity profile by privately exchanging approximately $884 million aggregate principal amount of our existing 6.625% Senior Notes due 2020, 6.875% Senior Notes due 2020, 6.125% Senior Notes due 2021 and 5.375% Senior Notes due 2021 for approximately $919 million aggregate principal amount of new 8.00% Senior Notes due 2026; and
|
•
|
improved our cost structure by reducing combined production, gathering, processing and transportation and general and administrative expenses by approximately $0.79 per boe, or $290 million in 2019 compared to 2018, or 13%. The primary driver in the reduction is lower gathering, processing and transportation expenses due to certain 2018 divestitures and recently renegotiated contracts.
|
•
|
reduce total leverage to achieve long-term net debt/EBITDAX of 2x;
|
•
|
achieve sustained free cash flow generation;
|
•
|
improve margins through financial discipline and operating efficiencies; and
|
•
|
maintain industry leading environmental and safety performance.
|
Oil Derivatives(a)
|
|||||||
Year
|
|
Type of Derivative Instrument
|
|
Notional Volume
|
|
Average NYMEX Price
|
|
|
|
|
|
(mmbbls)
|
|
|
|
2020
|
|
Swaps
|
|
30
|
|
|
$59.59
|
2020
|
|
Two-way collars
|
|
2
|
|
|
$65.00/$83.25
|
2020
|
|
Basis protection swaps
|
|
12
|
|
|
$2.57
|
2021
|
|
Calls
|
|
4
|
|
|
$61.58
|
2022
|
|
Calls
|
|
4
|
|
|
$61.58
|
|
|
|
|
|
|
|
|
Natural Gas Derivatives(a)
|
|||||||
Year
|
|
Type of Derivative Instrument
|
|
Notional Volume
|
|
Average NYMEX Price
|
|
|
|
|
|
(bcf)
|
|
|
|
2020
|
|
Swaps
|
|
265
|
|
|
$2.76
|
2020
|
|
Calls
|
|
22
|
|
|
$12.00
|
2020
|
|
Basis protection swaps
|
|
53
|
|
|
$0.03
|
2020
|
|
Put spread(b)
|
|
94
|
|
|
$1.80/$2.05
|
2021
|
|
Call swaptions
|
|
15
|
|
|
$2.80
|
2021
|
|
Calls
|
|
96
|
|
|
$2.75
|
2022
|
|
Call swaption
|
|
15
|
|
|
$2.80
|
(a)
|
Includes amounts settled in January and February 2020.
|
(b)
|
Put spread: These instruments contain a fixed floor price (bought put) and sub floor price (sold put). If the market price exceeds the bought put strike, we receive the market price. If the market price is between the bought put and sold put strike prices, we receive the bought put price. If the market price falls below the subfloor, we receive the market price plus the difference between the sold put and bought put.
|
|
|
Payments Due By Period
|
||||||||||||||||||
|
|
Total
|
|
2020
|
|
2021-2022
|
|
2023-2024
|
|
2025 and Beyond
|
||||||||||
|
|
($ in millions)
|
||||||||||||||||||
Long-term debt:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Principal(a)
|
|
$
|
8,916
|
|
|
$
|
385
|
|
|
$
|
583
|
|
|
$
|
3,888
|
|
|
$
|
4,060
|
|
Interest
|
|
3,314
|
|
|
705
|
|
|
1,338
|
|
|
1,101
|
|
|
170
|
|
|||||
Finance lease obligation(b)
|
|
20
|
|
|
10
|
|
|
10
|
|
|
—
|
|
|
—
|
|
|||||
Operating lease obligations(c)
|
|
28
|
|
|
10
|
|
|
9
|
|
|
4
|
|
|
5
|
|
|||||
Operating commitments(d)
|
|
8,056
|
|
|
1,143
|
|
|
1,955
|
|
|
1,479
|
|
|
3,479
|
|
|||||
Standby letters of credit
|
|
59
|
|
|
59
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||
VPP obligation(e)
|
|
64
|
|
|
55
|
|
|
9
|
|
|
—
|
|
|
—
|
|
|||||
Other
|
|
13
|
|
|
3
|
|
|
8
|
|
|
2
|
|
|
—
|
|
|||||
Total contractual cash obligations(f)
|
|
$
|
20,470
|
|
|
$
|
2,370
|
|
|
$
|
3,912
|
|
|
$
|
6,474
|
|
|
$
|
7,714
|
|
(a)
|
See Note 5 of the notes to our consolidated financial statements included in Item 8 of this report for a description of our long-term debt.
|
(b)
|
See Note 8 of the notes to our consolidated financial statements included in Item 8 of this report for a description of our finance lease obligation.
|
(c)
|
See Note 8 of the notes to our consolidated financial statements included in Item 8 of this report for a description of our operating lease obligations.
|
(d)
|
See Note 6 of the notes to our consolidated financial statements included in Item 8 of this report for a description of our gathering, processing and transportation agreements and service contract commitments.
|
(e)
|
See Note 7 of the notes to our consolidated financial statements included in Item 8 of this report for a discussion of our VPP obligation.
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Cash provided by operating activities
|
|
$
|
1,623
|
|
|
$
|
1,730
|
|
|
$
|
475
|
|
Proceeds from issuances of debt, net
|
|
1,563
|
|
|
1,236
|
|
|
1,585
|
|
|||
Proceeds from revolving credit facility borrowings, net
|
|
496
|
|
|
—
|
|
|
781
|
|
|||
Proceeds from divestitures of proved and unproved properties, net
|
|
130
|
|
|
2,231
|
|
|
1,249
|
|
|||
Proceeds from sales of other property and equipment, net
|
|
6
|
|
|
147
|
|
|
55
|
|
|||
Proceeds from sales of investments
|
|
—
|
|
|
74
|
|
|
—
|
|
|||
Total sources of cash and cash equivalents
|
|
$
|
3,818
|
|
|
$
|
5,418
|
|
|
$
|
4,145
|
|
|
|
Years Ended December 31,
|
||||||||||||||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||||||||||||||
|
|
Principal Amount
of Debt
Issued
|
|
Net
Proceeds
|
|
Principal Amount
of Debt
Issued
|
|
Net
Proceeds
|
|
Principal Amount
of Debt
Issued
|
|
Net
Proceeds |
||||||||||||
|
|
($ in millions)
|
||||||||||||||||||||||
Term loan
|
|
$
|
1,500
|
|
|
$
|
1,455
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
Senior secured second lien notes
|
|
120
|
|
|
108
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||
Senior notes
|
|
—
|
|
|
—
|
|
|
1,250
|
|
|
1,236
|
|
|
1,600
|
|
|
1,585
|
|
||||||
Total
|
|
$
|
1,620
|
|
|
$
|
1,563
|
|
|
$
|
1,250
|
|
|
$
|
1,236
|
|
|
$
|
1,600
|
|
|
$
|
1,585
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Oil and Natural Gas Expenditures:
|
|
|
|
|
|
|
||||||
Drilling and completion costs
|
|
$
|
2,180
|
|
|
$
|
1,848
|
|
|
$
|
2,113
|
|
Acquisitions of proved and unproved properties
|
|
35
|
|
|
128
|
|
|
88
|
|
|||
Total oil and natural gas expenditures
|
|
2,215
|
|
|
1,976
|
|
|
2,201
|
|
|||
Other Uses of Cash and Cash Equivalents:
|
|
|
|
|
|
|
||||||
Cash paid to purchase debt
|
|
1,073
|
|
|
2,813
|
|
|
2,592
|
|
|||
Business combination, net
|
|
353
|
|
|
—
|
|
|
—
|
|
|||
Payments on revolving credit facility borrowings, net
|
|
—
|
|
|
362
|
|
|
—
|
|
|||
Extinguishment of other financing
|
|
—
|
|
|
122
|
|
|
—
|
|
|||
Additions to other property and equipment
|
|
48
|
|
|
21
|
|
|
21
|
|
|||
Cash paid for preferred stock dividends
|
|
91
|
|
|
92
|
|
|
183
|
|
|||
Distributions to noncontrolling interest owners
|
|
4
|
|
|
6
|
|
|
8
|
|
|||
Other
|
|
32
|
|
|
27
|
|
|
17
|
|
|||
Total other uses of cash and cash equivalents
|
|
1,601
|
|
|
3,443
|
|
|
2,821
|
|
|||
Total uses of cash and cash equivalents
|
|
$
|
3,816
|
|
|
$
|
5,419
|
|
|
$
|
5,022
|
|
|
|
2019
|
|||||||||||||||||||||||||
|
|
Oil
|
|
Natural Gas
|
|
NGL
|
|
Total
|
|||||||||||||||||||
|
|
mbbl
per day
|
|
$/bbl
|
|
mmcf
per day
|
|
$/mcf
|
|
mbbl
per day
|
|
$/bbl
|
|
mboe
per day
|
|
%
|
|
$/boe
|
|||||||||
Marcellus
|
|
—
|
|
|
—
|
|
|
946
|
|
|
2.48
|
|
|
—
|
|
|
—
|
|
|
158
|
|
|
33
|
|
|
14.88
|
|
Haynesville
|
|
—
|
|
|
—
|
|
|
702
|
|
|
2.42
|
|
|
—
|
|
|
—
|
|
|
117
|
|
|
24
|
|
|
14.50
|
|
Eagle Ford
|
|
58
|
|
|
61.22
|
|
|
153
|
|
|
2.73
|
|
|
19
|
|
|
17.04
|
|
|
102
|
|
|
21
|
|
|
41.72
|
|
Brazos Valley
|
|
33
|
|
|
59.29
|
|
|
49
|
|
|
1.79
|
|
|
5
|
|
|
8.04
|
|
|
47
|
|
|
10
|
|
|
44.96
|
|
Powder River Basin
|
|
19
|
|
|
54.28
|
|
|
86
|
|
|
2.47
|
|
|
5
|
|
|
16.63
|
|
|
38
|
|
|
8
|
|
|
34.31
|
|
Mid-Continent
|
|
8
|
|
|
55.69
|
|
|
57
|
|
|
2.13
|
|
|
4
|
|
|
18.02
|
|
|
21
|
|
|
4
|
|
|
29.91
|
|
Retained assets(a)
|
|
118
|
|
|
59.16
|
|
|
1,993
|
|
|
2.45
|
|
|
33
|
|
|
15.62
|
|
|
483
|
|
|
100
|
|
|
25.57
|
|
Divested assets(b)
|
|
—
|
|
|
—
|
|
|
2
|
|
|
0.40
|
|
|
—
|
|
|
—
|
|
|
1
|
|
|
—
|
|
|
17.55
|
|
Total
|
|
118
|
|
|
59.16
|
|
|
1,995
|
|
|
2.45
|
|
|
33
|
|
|
15.62
|
|
|
484
|
|
|
100
|
%
|
|
25.57
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||
|
|
2018
|
|||||||||||||||||||||||||
|
|
Oil
|
|
Natural Gas
|
|
NGL
|
|
Total
|
|||||||||||||||||||
|
|
mbbl
per day
|
|
$/bbl
|
|
mmcf
per day
|
|
$/mcf
|
|
mbbl
per day
|
|
$/bbl
|
|
mboe
per day
|
|
%
|
|
$/boe
|
|||||||||
Marcellus
|
|
—
|
|
|
—
|
|
|
828
|
|
|
3.06
|
|
|
—
|
|
|
—
|
|
|
138
|
|
|
26
|
|
|
18.38
|
|
Haynesville
|
|
—
|
|
|
—
|
|
|
788
|
|
|
2.90
|
|
|
—
|
|
|
—
|
|
|
131
|
|
|
25
|
|
|
17.42
|
|
Eagle Ford
|
|
60
|
|
|
69.02
|
|
|
136
|
|
|
3.46
|
|
|
20
|
|
|
25.59
|
|
|
102
|
|
|
20
|
|
|
50.01
|
|
Powder River Basin
|
|
11
|
|
|
63.36
|
|
|
64
|
|
|
2.90
|
|
|
4
|
|
|
26.83
|
|
|
25
|
|
|
5
|
|
|
38.12
|
|
Mid-Continent
|
|
9
|
|
|
64.17
|
|
|
60
|
|
|
2.77
|
|
|
4
|
|
|
26.50
|
|
|
24
|
|
|
5
|
|
|
36.61
|
|
Retained assets(a)
|
|
80
|
|
|
67.72
|
|
|
1,876
|
|
|
3.01
|
|
|
28
|
|
|
25.90
|
|
|
420
|
|
|
81
|
|
|
27.97
|
|
Divested assets(b)
|
|
10
|
|
|
63.54
|
|
|
402
|
|
|
2.90
|
|
|
24
|
|
|
27.21
|
|
|
101
|
|
|
19
|
|
|
24.37
|
|
Total
|
|
90
|
|
|
67.25
|
|
|
2,278
|
|
|
2.99
|
|
|
52
|
|
|
26.50
|
|
|
521
|
|
|
100
|
%
|
|
27.27
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||
|
|
2017
|
|||||||||||||||||||||||||
|
|
Oil
|
|
Natural Gas
|
|
NGL
|
|
Total
|
|||||||||||||||||||
|
|
mbbl
per day
|
|
$/bbl
|
|
mmcf
per day
|
|
$/mcf
|
|
mbbl
per day
|
|
$/bbl
|
|
mboe
per day
|
|
%
|
|
$/boe
|
|||||||||
Marcellus
|
|
—
|
|
|
—
|
|
|
804
|
|
|
2.45
|
|
|
—
|
|
|
—
|
|
|
134
|
|
|
25
|
|
|
14.67
|
|
Haynesville
|
|
—
|
|
|
—
|
|
|
784
|
|
|
2.85
|
|
|
—
|
|
|
—
|
|
|
131
|
|
|
24
|
|
|
17.10
|
|
Eagle Ford
|
|
58
|
|
|
52.37
|
|
|
141
|
|
|
3.31
|
|
|
18
|
|
|
22.98
|
|
|
100
|
|
|
18
|
|
|
39.33
|
|
Powder River Basin
|
|
6
|
|
|
50.06
|
|
|
37
|
|
|
3.01
|
|
|
3
|
|
|
27.37
|
|
|
15
|
|
|
3
|
|
|
32.52
|
|
Mid-Continent
|
|
8
|
|
|
49.26
|
|
|
66
|
|
|
2.79
|
|
|
5
|
|
|
23.10
|
|
|
23
|
|
|
4
|
|
|
28.92
|
|
Retained assets(a)
|
|
72
|
|
|
51.82
|
|
|
1,832
|
|
|
2.71
|
|
|
26
|
|
|
23.42
|
|
|
403
|
|
|
74
|
|
|
23.05
|
|
Divested assets(b)
|
|
18
|
|
|
47.83
|
|
|
574
|
|
|
2.92
|
|
|
31
|
|
|
22.98
|
|
|
145
|
|
|
26
|
|
|
22.41
|
|
Total
|
|
90
|
|
|
51.03
|
|
|
2,406
|
|
|
2.76
|
|
|
57
|
|
|
23.18
|
|
|
548
|
|
|
100
|
%
|
|
22.88
|
|
(b)
|
Divested assets include certain Utica assets in Ohio in 2018 and Haynesville assets in 2017 as well as certain Mid-Continent assets in both 2018 and 2017.
|
|
|
Years Ended December 31,
|
||||||||||||||||
|
|
2019
|
|
change
|
|
2018
|
|
change
|
|
2017
|
||||||||
|
|
($ in millions)
|
||||||||||||||||
Oil
|
|
$
|
2,543
|
|
|
16
|
%
|
|
$
|
2,201
|
|
|
32
|
%
|
|
$
|
1,668
|
|
Natural gas
|
|
1,782
|
|
|
(28
|
)%
|
|
2,486
|
|
|
3
|
%
|
|
2,422
|
|
|||
NGL
|
|
192
|
|
|
(62
|
)%
|
|
502
|
|
|
4
|
%
|
|
484
|
|
|||
Oil, natural gas and NGL sales
|
|
$
|
4,517
|
|
|
(13
|
)%
|
|
$
|
5,189
|
|
|
13
|
%
|
|
$
|
4,574
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Oil derivatives – realized gains (losses)
|
|
$
|
36
|
|
|
$
|
(321
|
)
|
|
$
|
70
|
|
Oil derivatives – unrealized gains (losses)
|
|
(248
|
)
|
|
445
|
|
|
(134
|
)
|
|||
Total gains (losses) on oil derivatives
|
|
(212
|
)
|
|
124
|
|
|
(64
|
)
|
|||
|
|
|
|
|
|
|
||||||
Natural gas derivatives – realized gains (losses)
|
|
114
|
|
|
7
|
|
|
(9
|
)
|
|||
Natural gas derivatives – unrealized gains (losses)
|
|
103
|
|
|
(154
|
)
|
|
489
|
|
|||
Total gains (losses) on natural gas derivatives
|
|
217
|
|
|
(147
|
)
|
|
480
|
|
|||
|
|
|
|
|
|
|
||||||
NGL derivatives – realized gains (losses)
|
|
—
|
|
|
(13
|
)
|
|
(4
|
)
|
|||
NGL derivatives – unrealized gains (losses)
|
|
—
|
|
|
2
|
|
|
(1
|
)
|
|||
Total gains (losses) on NGL derivatives
|
|
—
|
|
|
(11
|
)
|
|
(5
|
)
|
|||
Total gains (losses) on oil, natural gas and NGL derivatives
|
|
$
|
5
|
|
|
$
|
(34
|
)
|
|
$
|
411
|
|
|
|
Years Ended December 31,
|
||||||||||||||||
|
|
2019
|
|
change
|
|
2018
|
|
change
|
|
2017
|
||||||||
|
|
($ in millions)
|
||||||||||||||||
Marketing revenues
|
|
$
|
3,967
|
|
|
(22
|
)%
|
|
$
|
5,076
|
|
|
13
|
%
|
|
$
|
4,511
|
|
Marketing expenses
|
|
4,003
|
|
|
(22
|
)%
|
|
5,158
|
|
|
12
|
%
|
|
4,598
|
|
|||
Marketing margin
|
|
$
|
(36
|
)
|
|
56
|
%
|
|
$
|
(82
|
)
|
|
6
|
%
|
|
$
|
(87
|
)
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Other revenue
|
|
$
|
63
|
|
|
$
|
63
|
|
|
$
|
67
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Gains (losses) on sales of assets
|
|
$
|
43
|
|
|
$
|
(264
|
)
|
|
$
|
476
|
|
|
|
Years Ended December 31,
|
||||||||||||||||
|
|
2019
|
|
change
|
|
2018
|
|
change
|
|
2017
|
||||||||
|
|
($ in millions)
|
||||||||||||||||
Oil, natural gas and NGL production expenses
|
|
|
|
|
|
|
|
|
|
|
||||||||
Marcellus
|
|
$
|
32
|
|
|
(6
|
)%
|
|
$
|
34
|
|
|
21
|
%
|
|
$
|
28
|
|
Haynesville
|
|
47
|
|
|
(18
|
)%
|
|
57
|
|
|
8
|
%
|
|
53
|
|
|||
Eagle Ford
|
|
180
|
|
|
(1
|
)%
|
|
181
|
|
|
(3
|
)%
|
|
187
|
|
|||
Brazos Valley
|
|
96
|
|
|
n/a
|
|
|
—
|
|
|
n/a
|
|
|
—
|
|
|||
Powder River Basin
|
|
71
|
|
|
45
|
%
|
|
49
|
|
|
69
|
%
|
|
29
|
|
|||
Mid-Continent
|
|
94
|
|
|
(4
|
)%
|
|
98
|
|
|
(8
|
)%
|
|
107
|
|
|||
Retained Assets(a)
|
|
520
|
|
|
24
|
%
|
|
419
|
|
|
4
|
%
|
|
404
|
|
|||
Divested Assets(b)
|
|
—
|
|
|
(100
|
)%
|
|
55
|
|
|
(51
|
)%
|
|
113
|
|
|||
Total oil, natural gas and NGL production expenses
|
|
$
|
520
|
|
|
10
|
%
|
|
$
|
474
|
|
|
(8
|
)%
|
|
$
|
517
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||
|
|
($ per boe)
|
||||||||||||||||
Oil, natural gas and NGL production expenses
|
|
|
|
|
|
|
|
|
|
|
||||||||
Marcellus
|
|
$
|
0.56
|
|
|
(16
|
)%
|
|
$
|
0.67
|
|
|
16
|
%
|
|
$
|
0.58
|
|
Haynesville
|
|
$
|
1.10
|
|
|
(8
|
)%
|
|
$
|
1.20
|
|
|
9
|
%
|
|
$
|
1.10
|
|
Eagle Ford
|
|
$
|
4.79
|
|
|
(2
|
)%
|
|
$
|
4.87
|
|
|
(5
|
)%
|
|
$
|
5.13
|
|
Brazos Valley
|
|
$
|
5.62
|
|
|
n/a
|
|
|
$
|
—
|
|
|
n/a
|
|
|
$
|
—
|
|
Powder River Basin
|
|
$
|
5.13
|
|
|
(4
|
)%
|
|
$
|
5.34
|
|
|
(3
|
)%
|
|
$
|
5.51
|
|
Mid-Continent
|
|
$
|
12.22
|
|
|
8
|
%
|
|
$
|
11.31
|
|
|
(8
|
)%
|
|
$
|
12.31
|
|
Retained Assets(a)
|
|
$
|
2.94
|
|
|
8
|
%
|
|
$
|
2.73
|
|
|
(1
|
)%
|
|
$
|
2.75
|
|
Divested Assets(b)
|
|
$
|
—
|
|
|
(100
|
)%
|
|
$
|
1.49
|
|
|
(30
|
)%
|
|
$
|
2.14
|
|
Total oil, natural gas and NGL production expenses per boe
|
|
$
|
2.94
|
|
|
18
|
%
|
|
$
|
2.50
|
|
|
(3
|
)%
|
|
$
|
2.59
|
|
(b)
|
Divested assets include certain Utica assets in Ohio in 2018 and Haynesville assets in 2017 as well as certain Mid-Continent assets in both 2018 and 2017.
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions, except per unit)
|
||||||||||
Oil, natural gas and NGL gathering, processing and transportation expenses
|
|
$
|
1,082
|
|
|
$
|
1,398
|
|
|
$
|
1,471
|
|
Oil ($ per bbl)
|
|
$
|
3.20
|
|
|
$
|
4.30
|
|
|
$
|
3.94
|
|
Natural gas ($ per mcf)
|
|
$
|
1.21
|
|
|
$
|
1.32
|
|
|
$
|
1.34
|
|
NGL ($ per bbl)
|
|
$
|
5.32
|
|
|
$
|
8.37
|
|
|
$
|
7.88
|
|
Total ($ per boe)
|
|
$
|
6.13
|
|
|
$
|
7.35
|
|
|
$
|
7.36
|
|
|
|
Years Ended December 31,
|
||||||||||||||||
|
|
2019
|
|
change
|
|
2018
|
|
change
|
|
2017
|
||||||||
|
|
($ in millions, except per unit)
|
||||||||||||||||
Severance taxes
|
|
$
|
144
|
|
|
16
|
%
|
|
$
|
124
|
|
|
39
|
%
|
|
$
|
89
|
|
Ad valorem taxes
|
|
80
|
|
|
23
|
%
|
|
65
|
|
|
44
|
%
|
|
45
|
|
|||
Severance and ad valorem taxes
|
|
$
|
224
|
|
|
19
|
%
|
|
$
|
189
|
|
|
41
|
%
|
|
$
|
134
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||
Severance taxes per boe
|
|
$
|
0.81
|
|
|
25
|
%
|
|
$
|
0.65
|
|
|
48
|
%
|
|
$
|
0.44
|
|
Ad valorem taxes per boe
|
|
0.46
|
|
|
35
|
%
|
|
0.34
|
|
|
55
|
%
|
|
0.22
|
|
|||
Severance and ad valorem taxes per boe
|
|
$
|
1.27
|
|
|
28
|
%
|
|
$
|
0.99
|
|
|
50
|
%
|
|
$
|
0.66
|
|
|
|
Years Ended December 31,
|
||||||||||||||||
|
|
2019
|
|
change
|
|
2018
|
|
change
|
|
2017
|
||||||||
|
|
($ in millions, except per unit)
|
||||||||||||||||
Impairments of unproved properties
|
|
$
|
32
|
|
|
(46
|
)%
|
|
$
|
59
|
|
|
(72
|
)%
|
|
$
|
214
|
|
Dry hole expense
|
|
25
|
|
|
(32
|
)%
|
|
37
|
|
|
n/a
|
|
|
—
|
|
|||
Geological and geophysical expense and other
|
|
27
|
|
|
(59
|
)%
|
|
66
|
|
|
214
|
%
|
|
21
|
|
|||
Exploration expense
|
|
$
|
84
|
|
|
(48
|
)%
|
|
$
|
162
|
|
|
(31
|
)%
|
|
$
|
235
|
|
|
|
Years Ended December 31,
|
||||||||||||||||
|
|
2019
|
|
change
|
|
2018
|
|
change
|
|
2017
|
||||||||
|
|
($ in millions, except per unit)
|
||||||||||||||||
Gross overhead
|
|
$
|
682
|
|
|
(4
|
)%
|
|
$
|
714
|
|
|
(10
|
)%
|
|
$
|
791
|
|
Allocated to production expenses
|
|
(132
|
)
|
|
(6
|
)%
|
|
(141
|
)
|
|
(20
|
)%
|
|
(177
|
)
|
|||
Allocated to marketing expenses
|
|
(14
|
)
|
|
(30
|
)%
|
|
(20
|
)
|
|
(31
|
)%
|
|
(29
|
)
|
|||
Allocated to exploration expenses
|
|
(11
|
)
|
|
10
|
%
|
|
(10
|
)
|
|
67
|
%
|
|
(6
|
)
|
|||
Allocated to sand mine expense
|
|
(7
|
)
|
|
—
|
%
|
|
—
|
|
|
—
|
%
|
|
—
|
|
|||
Capitalized general and administrative expenses
|
|
(56
|
)
|
|
4
|
%
|
|
(54
|
)
|
|
(10
|
)%
|
|
(60
|
)
|
|||
Reimbursed from third parties
|
|
(147
|
)
|
|
(5
|
)%
|
|
(154
|
)
|
|
(17
|
)%
|
|
(186
|
)
|
|||
General and administrative expenses, net
|
|
$
|
315
|
|
|
(6
|
)%
|
|
$
|
335
|
|
|
1
|
%
|
|
$
|
333
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||
General and administrative expenses, net per boe
|
|
$
|
1.78
|
|
|
1
|
%
|
|
$
|
1.76
|
|
|
5
|
%
|
|
$
|
1.67
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Provision for legal contingencies, net
|
|
$
|
19
|
|
|
$
|
26
|
|
|
$
|
(38
|
)
|
|
|
Years Ended December 31,
|
||||||||||||||||
|
|
2019
|
|
change
|
|
2018
|
|
change
|
|
2017
|
||||||||
|
|
($ in millions, except per unit)
|
||||||||||||||||
Depreciation, depletion and amortization
|
|
$
|
2,264
|
|
|
30
|
%
|
|
$
|
1,737
|
|
|
2
|
%
|
|
$
|
1,697
|
|
Depreciation, depletion and amortization per boe
|
|
$
|
12.82
|
|
|
40
|
%
|
|
$
|
9.13
|
|
|
8
|
%
|
|
$
|
8.49
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Impairments due to lower forecasted commodity prices
|
|
$
|
8
|
|
|
$
|
23
|
|
|
$
|
27
|
|
Impairments due to reduction in future development(a)
|
|
—
|
|
|
—
|
|
|
560
|
|
|||
Impairments due to anticipated sale
|
|
—
|
|
|
55
|
|
|
222
|
|
|||
Total impairments of oil and natural gas properties
|
|
8
|
|
|
78
|
|
|
809
|
|
|||
Impairments of other fixed assets
|
|
3
|
|
|
53
|
|
|
5
|
|
|||
Total impairments
|
|
$
|
11
|
|
|
$
|
131
|
|
|
$
|
814
|
|
(a)
|
The impairment was the result of an updated development plan in 2017, which included a removal of PUDs from properties in the process of being divested in the Mid-Continent operating area.
|
|
|
Years Ended December 31,
|
|||||||||||||||
|
|
2019
|
|
change
|
|
2018
|
|
change
|
|
2017
|
|||||||
|
|
($ in millions)
|
|||||||||||||||
Other operating expense
|
|
$
|
92
|
|
|
n/a
|
|
$
|
—
|
|
|
(100
|
)%
|
|
$
|
416
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Interest expense on senior notes
|
|
$
|
578
|
|
|
$
|
591
|
|
|
$
|
551
|
|
Interest expense on term loan
|
|
4
|
|
|
86
|
|
|
127
|
|
|||
Amortization of loan discount, issuance costs and other
|
|
3
|
|
|
24
|
|
|
40
|
|
|||
Amortization of premium
|
|
(5
|
)
|
|
(88
|
)
|
|
(138
|
)
|
|||
Interest expense on revolving credit facility
|
|
96
|
|
|
37
|
|
|
39
|
|
|||
Realized gains on interest rate derivatives
|
|
(5
|
)
|
|
(3
|
)
|
|
(3
|
)
|
|||
Unrealized losses on interest rate derivatives
|
|
4
|
|
|
2
|
|
|
4
|
|
|||
Capitalized interest
|
|
(24
|
)
|
|
(16
|
)
|
|
(19
|
)
|
|||
Total interest expense
|
|
$
|
651
|
|
|
$
|
633
|
|
|
$
|
601
|
|
|
|
|
|
|
|
|
||||||
Interest expense per boe
|
|
$
|
3.68
|
|
|
$
|
3.33
|
|
|
$
|
2.99
|
|
|
|
|
|
|
|
|
||||||
Average senior notes borrowings
|
|
$
|
7,857
|
|
|
$
|
8,160
|
|
|
$
|
7,714
|
|
Average credit facility borrowings
|
|
$
|
1,934
|
|
|
$
|
505
|
|
|
$
|
443
|
|
Average term loan borrowings
|
|
$
|
37
|
|
|
$
|
911
|
|
|
$
|
1,446
|
|
•
|
taxable income projections in future years;
|
•
|
reversal of existing deferred tax liabilities against deferred tax assets and whether the carryforward period is so brief that it would limit realization of the tax benefit;
|
•
|
future sales and operating cost projections that will produce more than enough taxable income to realize the deferred tax asset based on existing sales prices and cost structures; and
|
•
|
our earnings history exclusive of any loss that creates a future deductible amount coupled with evidence indicating that the loss is an aberration rather than a continuing condition.
|
ITEM 7A.
|
Quantitative and Qualitative Disclosures About Market Risk
|
•
|
Swaps: We receive a fixed price and pay a floating market price to the counterparty for the hedged commodity. In exchange for higher fixed prices on certain of our swap trades, we may sell call options and call swaptions.
|
•
|
Options: We sell, and occasionally buy, call options in exchange for a premium. At the time of settlement, if the market price exceeds the fixed price of the call option, we pay the counterparty the excess on sold call options and we receive the excess on bought call options. If the market price settles below the fixed price of the call option, no payment is due from either party.
|
•
|
Call Swaptions: We sell call swaptions to counterparties in exchange for a premium. Swaptions allow the counterparty, on a specific date, to extend an existing fixed-price swap for a certain period of time or to increase the notional volumes of an existing fixed-price swap.
|
•
|
Collars: These instruments contain a fixed floor price (put) and ceiling price (call). If the market price exceeds the call strike price or falls below the put strike price, we receive the fixed price and pay the market price. If the market price is between the put and the call strike prices, no payments are due from either party. Three-way collars include the sale by us of an additional put option in exchange for a more favorable strike price on the call option. This eliminates the counterparty’s downside exposure below the second put option strike price.
|
•
|
Basis Protection Swaps: These instruments are arrangements that guarantee a fixed price differential to NYMEX from a specified delivery point. We receive the fixed price differential and pay the floating market price differential to the counterparty for the hedged commodity.
|
|
|
|
|
Weighted Average Price
|
|
Fair Value
|
|||||||||||||||||
|
|
Volume
|
|
Fixed
|
|
Call
|
|
Put
|
|
Differential
|
|
Asset
(Liability) |
|||||||||||
|
|
(mmbbl)
|
|
($ per bbl)
|
|
($ in millions)
|
|||||||||||||||||
Oil:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Swaps:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Short-term
|
|
24
|
|
|
$
|
58.54
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
(7
|
)
|
Collars:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Short-term
|
|
2
|
|
|
$
|
—
|
|
|
$
|
83.25
|
|
|
$
|
65.00
|
|
|
$
|
—
|
|
|
14
|
|
|
Basis Protection Swaps:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Short-term
|
|
8
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
2.49
|
|
|
(2
|
)
|
|
Total Oil
|
|
5
|
|
||||||||||||||||||||
|
|
(bcf)
|
|
($ per mcf)
|
|
|
|||||||||||||||||
Natural Gas:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Swaps:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Short-term
|
|
265
|
|
|
$
|
2.76
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
125
|
|
|
Call Options (sold):
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Short-term
|
|
22
|
|
|
$
|
—
|
|
|
$
|
12.00
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
—
|
|
|
Call Swaptions:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Long-term
|
|
29
|
|
|
$
|
2.80
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
(2
|
)
|
|
Basis Protection Swaps:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Short-term
|
|
30
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
0.08
|
|
|
2
|
|
|
Total Natural Gas
|
|
125
|
|
||||||||||||||||||||
Total Commodities
|
|
$
|
130
|
|
|
|
|
|
Weighted Average Price
|
|
Fair Value
|
|||||||||||||||||
|
|
Volume
|
|
Fixed
|
|
Call
|
|
Put
|
|
Differential
|
|
Asset
(Liability)
|
|||||||||||
|
|
(mmbbl)
|
|
($ per bbl)
|
|
($ in millions)
|
|||||||||||||||||
Oil:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Swaps:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Short-term
|
|
10
|
|
|
$
|
58.97
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
117
|
|
Long-term
|
|
2
|
|
|
$
|
68.14
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
40
|
|
|
Collars:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Short-term
|
|
6
|
|
|
$
|
—
|
|
|
$
|
67.75
|
|
|
$
|
58.00
|
|
|
$
|
—
|
|
|
68
|
|
|
Long-term
|
|
2
|
|
|
$
|
—
|
|
|
$
|
83.25
|
|
|
$
|
65.00
|
|
|
$
|
—
|
|
|
30
|
|
|
Basis Protection Swaps:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Short-term
|
|
7
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
6.01
|
|
|
5
|
|
|
Total Oil
|
|
260
|
|
||||||||||||||||||||
|
|
(bcf)
|
|
($ per mcf)
|
|
|
|||||||||||||||||
Natural Gas:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Swaps:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Short-term
|
|
447
|
|
|
$
|
2.87
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
11
|
|
|
Long-term
|
|
176
|
|
|
$
|
2.75
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
15
|
|
|
Three-Way Collars:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Short-term
|
|
88
|
|
|
$
|
—
|
|
|
$
|
3.10
|
|
|
$ 2.50/2.80
|
|
|
$
|
—
|
|
|
1
|
|
||
Collars:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Short-term
|
|
55
|
|
|
$
|
—
|
|
|
$
|
3.02
|
|
|
$
|
2.75
|
|
|
$
|
—
|
|
|
(3
|
)
|
|
Call Options (sold):
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Short-term
|
|
22
|
|
|
$
|
—
|
|
|
$
|
12.00
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
—
|
|
|
Long-term
|
|
22
|
|
|
$
|
—
|
|
|
$
|
12.00
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
—
|
|
|
Call Swaptions:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Long-term
|
|
106
|
|
|
$
|
2.77
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
(9
|
)
|
|
Basis Protection Swaps:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Short-term
|
|
50
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
(0.56
|
)
|
|
—
|
|
|
Total Natural Gas
|
|
15
|
|
||||||||||||||||||||
Total Commodities
|
|
275
|
|
||||||||||||||||||||
Contingent Consideration:
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
Utica Divestiture:
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Short-term
|
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
7
|
|
|
Total Derivative Asset
|
|
$
|
282
|
|
|
Years of Maturity
|
|
|
||||||||||||||||||||||||
|
2020
|
|
2021
|
|
2022
|
|
2023
|
|
2024
|
|
Thereafter
|
|
Total
|
||||||||||||||
|
($ in millions)
|
||||||||||||||||||||||||||
Liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Debt – fixed rate
|
$
|
385
|
|
|
$
|
294
|
|
|
$
|
289
|
|
|
$
|
174
|
|
|
$
|
624
|
|
|
$
|
4,060
|
|
|
$
|
5,826
|
|
Average interest rate
|
6.38
|
%
|
|
5.80
|
%
|
|
4.88
|
%
|
|
5.75
|
%
|
|
7.00
|
%
|
|
9.34
|
%
|
|
8.39
|
%
|
|||||||
Debt – variable rate
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
1,590
|
|
|
$
|
1,500
|
|
|
$
|
—
|
|
|
$
|
3,090
|
|
Average interest rate
|
—
|
%
|
|
—
|
%
|
|
—
|
%
|
|
4.78
|
%
|
|
9.93
|
%
|
|
—
|
%
|
|
7.28
|
%
|
|
INDEX TO FINANCIAL STATEMENTS
CHESAPEAKE ENERGY CORPORATION
|
|
||
|
|
Page
|
||
Consolidated Financial Statements:
|
|
|||
|
Consolidated Balance Sheets as of December 31, 2019 and 2018
|
|||
|
for the Years Ended December 31, 2019, 2018 and 2017
|
|||
|
for the Years Ended December 31, 2019, 2018 and 2017
|
|||
|
for the Years Ended December 31, 2019, 2018 and 2017
|
|||
|
for the Years Ended December 31, 2019, 2018 and 2017
|
|||
Notes to the Consolidated Financial Statements:
|
|
|||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
||||
|
|
||||
|
|
|
|
|
Supplementary Information:
|
|
|||
|
||||
|
/s/ ROBERT D. LAWLER
|
|
|||
Robert D. Lawler
|
||||
President and Chief Executive Officer
|
||||
|
|
|
||
/s/ DOMENIC J. DELL'OSSO, JR.
|
|
|||
Domenic J. Dell'Osso, Jr.
|
||||
Executive Vice President and Chief Financial Officer
|
||||
|
|
|
|
|
|
|
|
|
|
February 27, 2020
|
||||
|
|
|
|
|
|
|
December 31,
|
||||||
|
|
2019
|
|
2018
|
||||
|
|
($ in millions)
|
||||||
CURRENT ASSETS:
|
|
|
|
|
||||
Cash and cash equivalents ($2 and $1 attributable to our VIE)
|
|
$
|
6
|
|
|
$
|
4
|
|
Accounts receivable, net
|
|
990
|
|
|
1,247
|
|
||
Short-term derivative assets
|
|
134
|
|
|
209
|
|
||
Other current assets
|
|
121
|
|
|
138
|
|
||
Total Current Assets
|
|
1,251
|
|
|
1,598
|
|
||
PROPERTY AND EQUIPMENT:
|
|
|
|
|
||||
Oil and natural gas properties, at cost based on successful efforts accounting:
|
|
|
|
|
||||
Proved oil and natural gas properties
($755 and $755 attributable to our VIE)
|
|
30,765
|
|
|
25,407
|
|
||
Unproved properties
|
|
2,173
|
|
|
1,561
|
|
||
Other property and equipment
|
|
1,810
|
|
|
1,721
|
|
||
Total Property and Equipment, at Cost
|
|
34,748
|
|
|
28,689
|
|
||
Less: accumulated depreciation, depletion and amortization
(($713) and ($707) attributable to our VIE)
|
|
(20,002
|
)
|
|
(17,886
|
)
|
||
Property and equipment held for sale, net
|
|
10
|
|
|
15
|
|
||
Total Property and Equipment, Net
|
|
14,756
|
|
|
10,818
|
|
||
LONG-TERM ASSETS:
|
|
|
|
|
||||
Long-term derivative assets
|
|
—
|
|
|
76
|
|
||
Other long-term assets
|
|
186
|
|
|
243
|
|
||
TOTAL ASSETS
|
|
$
|
16,193
|
|
|
$
|
12,735
|
|
|
|
|
|
|
|
|
December 31,
|
||||||
|
|
2019
|
|
2018
|
||||
|
|
($ in millions)
|
||||||
CURRENT LIABILITIES:
|
|
|
|
|
||||
Accounts payable
|
|
$
|
498
|
|
|
$
|
763
|
|
Current maturities of long-term debt, net
|
|
385
|
|
|
381
|
|
||
Accrued interest
|
|
75
|
|
|
141
|
|
||
Short-term derivative liabilities
|
|
2
|
|
|
3
|
|
||
Other current liabilities ($1 and $2 attributable to our VIE)
|
|
1,432
|
|
|
1,599
|
|
||
Total Current Liabilities
|
|
2,392
|
|
|
2,887
|
|
||
LONG-TERM LIABILITIES:
|
|
|
|
|
||||
Long-term debt, net
|
|
9,073
|
|
|
7,341
|
|
||
Long-term derivative liabilities
|
|
2
|
|
|
—
|
|
||
Asset retirement obligations, net of current portion
|
|
200
|
|
|
155
|
|
||
Other long-term liabilities
|
|
125
|
|
|
219
|
|
||
Total Long-Term Liabilities
|
|
9,400
|
|
|
7,715
|
|
||
|
|
|
|
|||||
EQUITY:
|
|
|
|
|
||||
Chesapeake Stockholders’ Equity:
|
|
|
|
|
||||
Preferred stock, $0.01 par value, 20,000,000 shares authorized:
5,563,458 and 5,603,458 shares outstanding |
|
1,631
|
|
|
1,671
|
|
||
Common stock, $0.01 par value,
3,000,000,000 and 2,000,000,000 shares authorized:
1,954,558,617 and 913,715,512 shares issued
|
|
19
|
|
|
9
|
|
||
Additional paid-in capital
|
|
16,954
|
|
|
14,378
|
|
||
Accumulated deficit
|
|
(14,220
|
)
|
|
(13,912
|
)
|
||
Accumulated other comprehensive income (loss)
|
|
12
|
|
|
(23
|
)
|
||
Less: treasury stock, at cost;
5,244,992 and 3,246,553 common shares
|
|
(32
|
)
|
|
(31
|
)
|
||
Total Chesapeake Stockholders’ Equity
|
|
4,364
|
|
|
2,092
|
|
||
Noncontrolling interests
|
|
37
|
|
|
41
|
|
||
Total Equity
|
|
4,401
|
|
|
2,133
|
|
||
TOTAL LIABILITIES AND EQUITY
|
|
$
|
16,193
|
|
|
$
|
12,735
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions except per share data)
|
||||||||||
REVENUES AND OTHER:
|
|
|
|
|
|
|
||||||
Oil, natural gas and NGL
|
|
$
|
4,522
|
|
|
$
|
5,155
|
|
|
$
|
4,985
|
|
Marketing
|
|
3,967
|
|
|
5,076
|
|
|
4,511
|
|
|||
Total Revenues
|
|
8,489
|
|
|
10,231
|
|
|
9,496
|
|
|||
Other
|
|
63
|
|
|
63
|
|
|
67
|
|
|||
Gains (losses) on sales of assets
|
|
43
|
|
|
(264
|
)
|
|
476
|
|
|||
Total Revenues and Other
|
|
8,595
|
|
|
10,030
|
|
|
10,039
|
|
|||
OPERATING EXPENSES:
|
|
|
|
|
|
|
||||||
Oil, natural gas and NGL production
|
|
520
|
|
|
474
|
|
|
517
|
|
|||
Oil, natural gas and NGL gathering, processing and transportation
|
|
1,082
|
|
|
1,398
|
|
|
1,471
|
|
|||
Severance and ad valorem taxes
|
|
224
|
|
|
189
|
|
|
134
|
|
|||
Exploration
|
|
84
|
|
|
162
|
|
|
235
|
|
|||
Marketing
|
|
4,003
|
|
|
5,158
|
|
|
4,598
|
|
|||
General and administrative
|
|
315
|
|
|
335
|
|
|
333
|
|
|||
Restructuring and other termination costs
|
|
12
|
|
|
38
|
|
|
—
|
|
|||
Provision for legal contingencies, net
|
|
19
|
|
|
26
|
|
|
(38
|
)
|
|||
Depreciation, depletion and amortization
|
|
2,264
|
|
|
1,737
|
|
|
1,697
|
|
|||
Impairments
|
|
11
|
|
|
131
|
|
|
814
|
|
|||
Other operating expense
|
|
92
|
|
|
—
|
|
|
416
|
|
|||
Total Operating Expenses
|
|
8,626
|
|
|
9,648
|
|
|
10,177
|
|
|||
INCOME (LOSS) FROM OPERATIONS
|
|
(31
|
)
|
|
382
|
|
|
(138
|
)
|
|||
OTHER INCOME (EXPENSE):
|
|
|
|
|
|
|
||||||
Interest expense
|
|
(651
|
)
|
|
(633
|
)
|
|
(601
|
)
|
|||
Gains (losses) on investments
|
|
(71
|
)
|
|
139
|
|
|
—
|
|
|||
Gains on purchases or exchanges of debt
|
|
75
|
|
|
263
|
|
|
233
|
|
|||
Other income
|
|
39
|
|
|
67
|
|
|
6
|
|
|||
Total Other Expense
|
|
(608
|
)
|
|
(164
|
)
|
|
(362
|
)
|
|||
INCOME (LOSS) BEFORE INCOME TAXES
|
|
(639
|
)
|
|
218
|
|
|
(500
|
)
|
|||
INCOME TAX EXPENSE (BENEFIT):
|
|
|
|
|
|
|
||||||
Current income taxes
|
|
(26
|
)
|
|
—
|
|
|
(9
|
)
|
|||
Deferred income taxes
|
|
(305
|
)
|
|
(10
|
)
|
|
11
|
|
|||
Total Income Tax Expense (Benefit)
|
|
(331
|
)
|
|
(10
|
)
|
|
2
|
|
|||
NET INCOME (LOSS)
|
|
(308
|
)
|
|
228
|
|
|
(502
|
)
|
|||
Net income attributable to noncontrolling interests
|
|
—
|
|
|
(2
|
)
|
|
(3
|
)
|
|||
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE
|
|
(308
|
)
|
|
226
|
|
|
(505
|
)
|
|||
Preferred stock dividends
|
|
(91
|
)
|
|
(92
|
)
|
|
(85
|
)
|
|||
Loss on exchange of preferred stock
|
|
(17
|
)
|
|
—
|
|
|
(41
|
)
|
|||
Earnings allocated to participating securities
|
|
—
|
|
|
(1
|
)
|
|
—
|
|
|||
NET INCOME (LOSS) AVAILABLE TO COMMON STOCKHOLDERS
|
|
$
|
(416
|
)
|
|
$
|
133
|
|
|
$
|
(631
|
)
|
EARNINGS (LOSS) PER COMMON SHARE:
|
|
|
|
|
|
|
||||||
Basic
|
|
$
|
(0.25
|
)
|
|
$
|
0.15
|
|
|
$
|
(0.70
|
)
|
Diluted
|
|
$
|
(0.25
|
)
|
|
$
|
0.15
|
|
|
$
|
(0.70
|
)
|
WEIGHTED AVERAGE COMMON AND COMMON
EQUIVALENT SHARES OUTSTANDING (in millions): |
|
|
|
|
|
|
||||||
Basic
|
|
1,665
|
|
|
909
|
|
|
906
|
|
|||
Diluted
|
|
1,665
|
|
|
909
|
|
|
906
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
NET INCOME (LOSS)
|
|
$
|
(308
|
)
|
|
$
|
228
|
|
|
$
|
(502
|
)
|
OTHER COMPREHENSIVE INCOME, NET OF INCOME TAX:
|
|
|
|
|
|
|
||||||
Unrealized gains (losses) on derivative instruments, net of income tax benefit of $0, $0, and $0
|
|
—
|
|
|
—
|
|
|
5
|
|
|||
Reclassification of losses on settled derivative instruments, net of income tax expense of $0, $0 and $0
|
|
35
|
|
|
34
|
|
|
34
|
|
|||
Other Comprehensive Income
|
|
35
|
|
|
34
|
|
|
39
|
|
|||
COMPREHENSIVE INCOME (LOSS)
|
|
(273
|
)
|
|
262
|
|
|
(463
|
)
|
|||
COMPREHENSIVE INCOME ATTRIBUTABLE TO
NONCONTROLLING INTERESTS
|
|
—
|
|
|
(2
|
)
|
|
(3
|
)
|
|||
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE
|
|
$
|
(273
|
)
|
|
$
|
260
|
|
|
$
|
(466
|
)
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES:
|
|
|
|
|
|
|
||||||
NET INCOME (LOSS)
|
|
$
|
(308
|
)
|
|
$
|
228
|
|
|
$
|
(502
|
)
|
ADJUSTMENTS TO RECONCILE NET INCOME (LOSS) TO CASH
PROVIDED BY OPERATING ACTIVITIES:
|
|
|
|
|
|
|
||||||
Depreciation, depletion and amortization
|
|
2,264
|
|
|
1,737
|
|
|
1,697
|
|
|||
Deferred income tax expense (benefit)
|
|
(305
|
)
|
|
(10
|
)
|
|
11
|
|
|||
Derivative (gains) losses, net
|
|
(3
|
)
|
|
26
|
|
|
(409
|
)
|
|||
Cash receipts (payments) on derivative settlements, net
|
|
202
|
|
|
(345
|
)
|
|
(18
|
)
|
|||
Stock-based compensation
|
|
30
|
|
|
32
|
|
|
49
|
|
|||
(Gains) losses on sales of assets
|
|
(43
|
)
|
|
264
|
|
|
(476
|
)
|
|||
Impairments
|
|
11
|
|
|
131
|
|
|
814
|
|
|||
Exploration
|
|
49
|
|
|
96
|
|
|
214
|
|
|||
(Gains) losses on investments
|
|
63
|
|
|
(139
|
)
|
|
—
|
|
|||
Gains on purchases or exchanges of debt
|
|
(79
|
)
|
|
(263
|
)
|
|
(235
|
)
|
|||
Other
|
|
(4
|
)
|
|
(118
|
)
|
|
(132
|
)
|
|||
(Increase) decrease in accounts receivable and other assets
|
|
376
|
|
|
16
|
|
|
(163
|
)
|
|||
(Decrease) increase in accounts payable, accrued liabilities and other
|
|
(630
|
)
|
|
75
|
|
|
(375
|
)
|
|||
Net Cash Provided By Operating Activities
|
|
1,623
|
|
|
1,730
|
|
|
475
|
|
|||
CASH FLOWS FROM INVESTING ACTIVITIES:
|
|
|
|
|
|
|
||||||
Drilling and completion costs
|
|
(2,180
|
)
|
|
(1,848
|
)
|
|
(2,113
|
)
|
|||
Business combination, net
|
|
(353
|
)
|
|
—
|
|
|
—
|
|
|||
Acquisitions of proved and unproved properties
|
|
(35
|
)
|
|
(128
|
)
|
|
(88
|
)
|
|||
Proceeds from divestitures of proved and unproved properties
|
|
130
|
|
|
2,231
|
|
|
1,249
|
|
|||
Additions to other property and equipment
|
|
(48
|
)
|
|
(21
|
)
|
|
(21
|
)
|
|||
Proceeds from sales of other property and equipment
|
|
6
|
|
|
147
|
|
|
55
|
|
|||
Proceeds from sales of investments
|
|
—
|
|
|
74
|
|
|
—
|
|
|||
Net Cash Provided By (Used In) Investing Activities
|
|
(2,480
|
)
|
|
455
|
|
|
(918
|
)
|
|||
|
|
|
|
|
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
PREFERRED STOCK:
|
|
|
|
|
|
|
||||||
Balance, beginning of period
|
|
$
|
1,671
|
|
|
$
|
1,671
|
|
|
$
|
1,771
|
|
Exchange/conversions of 40,000, 0 and 236,048 shares of
preferred stock for common stock
|
|
(40
|
)
|
|
—
|
|
|
(100
|
)
|
|||
Balance, end of period
|
|
1,631
|
|
|
1,671
|
|
|
1,671
|
|
|||
COMMON STOCK:
|
|
|
|
|
|
|
||||||
Balance, beginning of period
|
|
9
|
|
|
9
|
|
|
9
|
|
|||
Common shares issued for WildHorse Merger
|
|
7
|
|
|
—
|
|
|
—
|
|
|||
Exchange of senior notes and convertible notes
|
|
3
|
|
|
—
|
|
|
—
|
|
|||
Balance, end of period
|
|
19
|
|
|
9
|
|
|
9
|
|
|||
ADDITIONAL PAID-IN CAPITAL:
|
|
|
|
|
|
|
||||||
Balance, beginning of period
|
|
14,378
|
|
|
14,437
|
|
|
14,486
|
|
|||
Common shares issued for WildHorse Merger
|
|
2,030
|
|
|
—
|
|
|
—
|
|
|||
Stock-based compensation
|
|
27
|
|
|
33
|
|
|
54
|
|
|||
Exchange of contingent convertible notes for 73,389,094, 0 and 0 shares of common stock
|
|
134
|
|
|
—
|
|
|
—
|
|
|||
Exchange of senior notes for 235,563,519, 0 and 0 shares of common stock
|
|
438
|
|
|
—
|
|
|
—
|
|
|||
Exchange of preferred stock for 10,367,950, 0, and
9,965,835 shares of common stock
|
|
40
|
|
|
—
|
|
|
100
|
|
|||
Equity component of contingent convertible notes repurchased
|
|
(2
|
)
|
|
—
|
|
|
(20
|
)
|
|||
Dividends on preferred stock
|
|
(91
|
)
|
|
(92
|
)
|
|
(183
|
)
|
|||
Balance, end of period
|
|
16,954
|
|
|
14,378
|
|
|
14,437
|
|
|||
RETAINED EARNINGS (ACCUMULATED DEFICIT):
|
|
|
|
|
|
|
||||||
Balance, beginning of period
|
|
(13,912
|
)
|
|
(14,130
|
)
|
|
(13,625
|
)
|
|||
Net income (loss) attributable to Chesapeake
|
|
(308
|
)
|
|
226
|
|
|
(505
|
)
|
|||
Cumulative effect of change in accounting principle
|
|
—
|
|
|
(8
|
)
|
|
—
|
|
|||
Balance, end of period
|
|
(14,220
|
)
|
|
(13,912
|
)
|
|
(14,130
|
)
|
|||
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS):
|
|
|
|
|
|
|
||||||
Balance, beginning of period
|
|
(23
|
)
|
|
(57
|
)
|
|
(96
|
)
|
|||
Hedging activity
|
|
35
|
|
|
34
|
|
|
39
|
|
|||
Balance, end of period
|
|
12
|
|
|
(23
|
)
|
|
(57
|
)
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
TREASURY STOCK – COMMON:
|
|
|
|
|
|
|
||||||
Balance, beginning of period
|
|
(31
|
)
|
|
(31
|
)
|
|
(27
|
)
|
|||
Purchase of 2,878,234, 1,510,022, and 1,206,419 shares for company benefit plans
|
|
(7
|
)
|
|
(4
|
)
|
|
(7
|
)
|
|||
Release of 879,795, 503,863 and 186,529 shares from company benefit plans
|
|
6
|
|
|
4
|
|
|
3
|
|
|||
Balance, end of period
|
|
(32
|
)
|
|
(31
|
)
|
|
(31
|
)
|
|||
TOTAL CHESAPEAKE STOCKHOLDERS’ EQUITY
|
|
4,364
|
|
|
2,092
|
|
|
1,899
|
|
|||
NONCONTROLLING INTERESTS:
|
|
|
|
|
|
|
||||||
Balance, beginning of period
|
|
41
|
|
|
44
|
|
|
49
|
|
|||
Net income attributable to noncontrolling interests
|
|
—
|
|
|
2
|
|
|
3
|
|
|||
Distributions to noncontrolling interest owners
|
|
(4
|
)
|
|
(5
|
)
|
|
(8
|
)
|
|||
Balance, end of period
|
|
37
|
|
|
41
|
|
|
44
|
|
|||
TOTAL EQUITY
|
|
$
|
4,401
|
|
|
$
|
2,133
|
|
|
$
|
1,943
|
|
1.
|
Basis of Presentation and Summary of Significant Accounting Policies
|
|
|
Years Ended December 31,
|
||||||
|
|
2018
|
|
2017
|
||||
|
|
$ in millions
|
||||||
Oil, natural gas and NGL production, previously reported
|
|
$
|
539
|
|
|
$
|
562
|
|
Reclassification of ad valorem taxes
|
|
(65
|
)
|
|
(45
|
)
|
||
Oil, natural gas and NGL production, as currently reported
|
|
$
|
474
|
|
|
$
|
517
|
|
|
|
Years Ended December 31,
|
||||||
|
|
2018
|
|
2017
|
||||
|
|
$ in millions
|
||||||
Production taxes, previously reported
|
|
$
|
124
|
|
|
$
|
89
|
|
Reclassification of ad valorem taxes
|
|
65
|
|
|
45
|
|
||
Severance and ad valorem taxes, as currently reported
|
|
$
|
189
|
|
|
$
|
134
|
|
2.
|
Change in Accounting Principle
|
|
|
December 31, 2019
|
||||||||||
CONSOLIDATED BALANCE SHEETS
|
|
Under Full Cost
|
|
Adjustment
|
|
As
Reported Under Successful Efforts
|
||||||
|
|
($ in millions except per share data)
|
||||||||||
Proved oil and natural gas properties ($488 and $755 attributable to our VIE)
|
|
$
|
75,148
|
|
|
$
|
(44,383
|
)
|
|
$
|
30,765
|
|
Unproved properties
|
|
$
|
3,203
|
|
|
$
|
(1,030
|
)
|
|
$
|
2,173
|
|
Total Property and Equipment, at Cost
|
|
$
|
80,161
|
|
|
$
|
(45,413
|
)
|
|
$
|
34,748
|
|
Less: accumulated depreciation, depletion and amortization
(($468) and ($713) attributable to our VIE)
|
|
$
|
(66,626
|
)
|
|
$
|
46,624
|
|
|
$
|
(20,002
|
)
|
Total Property and Equipment, Net
|
|
$
|
13,545
|
|
|
$
|
1,211
|
|
|
$
|
14,756
|
|
Total Assets
|
|
$
|
14,982
|
|
|
$
|
1,211
|
|
|
$
|
16,193
|
|
Other current liabilities
|
|
$
|
1,377
|
|
|
$
|
55
|
|
|
$
|
1,432
|
|
Total Current Liabilities
|
|
$
|
2,337
|
|
|
$
|
55
|
|
|
$
|
2,392
|
|
Other long-term liabilities
|
|
$
|
116
|
|
|
$
|
9
|
|
|
$
|
125
|
|
Total Long-Term Liabilities
|
|
$
|
9,391
|
|
|
$
|
9
|
|
|
$
|
9,400
|
|
Accumulated deficit
|
|
$
|
(15,451
|
)
|
|
$
|
1,231
|
|
|
$
|
(14,220
|
)
|
Total Chesapeake Stockholders’ Equity
|
|
$
|
3,133
|
|
|
$
|
1,231
|
|
|
$
|
4,364
|
|
Noncontrolling interests
|
|
$
|
121
|
|
|
$
|
(84
|
)
|
|
$
|
37
|
|
Total Equity
|
|
$
|
3,254
|
|
|
$
|
1,147
|
|
|
$
|
4,401
|
|
Total Liabilities and Equity
|
|
$
|
14,982
|
|
|
$
|
1,211
|
|
|
$
|
16,193
|
|
|
|
December 31, 2018
|
||||||||||
CONSOLIDATED BALANCE SHEETS
|
|
As
Reported Under Full Cost
|
|
Adjustment
|
|
As
Reported Under Successful Efforts
|
||||||
|
|
($ in millions except per share data)
|
||||||||||
Proved oil and natural gas properties ($488 and $755 attributable to our VIE)
|
|
$
|
69,642
|
|
|
$
|
(44,235
|
)
|
|
$
|
25,407
|
|
Unproved properties
|
|
$
|
2,337
|
|
|
$
|
(776
|
)
|
|
$
|
1,561
|
|
Total Property and Equipment, at Cost
|
|
$
|
73,700
|
|
|
$
|
(45,011
|
)
|
|
$
|
28,689
|
|
Less: accumulated depreciation, depletion and amortization
(($461) and ($707) attributable to our VIE)
|
|
$
|
(64,685
|
)
|
|
$
|
46,799
|
|
|
$
|
(17,886
|
)
|
Total Property and Equipment, Net
|
|
$
|
9,030
|
|
|
$
|
1,788
|
|
|
$
|
10,818
|
|
Total Assets
|
|
$
|
10,947
|
|
|
$
|
1,788
|
|
|
$
|
12,735
|
|
Other current liabilities
|
|
$
|
1,540
|
|
|
$
|
59
|
|
|
$
|
1,599
|
|
Total Current Liabilities
|
|
$
|
2,828
|
|
|
$
|
59
|
|
|
$
|
2,887
|
|
Other long-term liabilities
|
|
$
|
156
|
|
|
$
|
63
|
|
|
$
|
219
|
|
Total Long-Term Liabilities
|
|
$
|
7,652
|
|
|
$
|
63
|
|
|
$
|
7,715
|
|
Accumulated deficit
|
|
$
|
(15,660
|
)
|
|
$
|
1,748
|
|
|
$
|
(13,912
|
)
|
Total Chesapeake Stockholders’ Equity
|
|
$
|
344
|
|
|
$
|
1,748
|
|
|
$
|
2,092
|
|
Noncontrolling interests
|
|
$
|
123
|
|
|
$
|
(82
|
)
|
|
$
|
41
|
|
Total Equity
|
|
$
|
467
|
|
|
$
|
1,666
|
|
|
$
|
2,133
|
|
Total Liabilities and Equity
|
|
$
|
10,947
|
|
|
$
|
1,788
|
|
|
$
|
12,735
|
|
|
|
|
|
|
Year Ended December 31, 2019
|
||||||||||
CONSOLIDATED STATEMENTS OF OPERATIONS
|
|
Under Full Cost
|
|
Adjustment
|
|
As
Reported Under Successful Efforts |
||||||
|
|
($ in millions except per share data)
|
||||||||||
Other revenues
|
|
$
|
—
|
|
|
$
|
63
|
|
|
$
|
63
|
|
Gain on sale of assets
|
|
$
|
—
|
|
|
$
|
43
|
|
|
$
|
43
|
|
Total revenues
|
|
$
|
8,489
|
|
|
$
|
106
|
|
|
$
|
8,595
|
|
Exploration expense
|
|
$
|
—
|
|
|
$
|
84
|
|
|
$
|
84
|
|
General and administrative
|
|
$
|
258
|
|
|
$
|
57
|
|
|
$
|
315
|
|
Depreciation, depletion and amortization
|
|
$
|
1,616
|
|
|
$
|
648
|
|
|
$
|
2,264
|
|
Gain on sale of oil and natural gas properties
|
|
$
|
(15
|
)
|
|
$
|
15
|
|
|
$
|
—
|
|
Impairments
|
|
$
|
344
|
|
|
$
|
(333
|
)
|
|
$
|
11
|
|
Other operating expense
|
|
$
|
94
|
|
|
$
|
(2
|
)
|
|
$
|
92
|
|
Total operating expenses
|
|
$
|
8,157
|
|
|
$
|
469
|
|
|
$
|
8,626
|
|
Income (loss) from operations
|
|
$
|
332
|
|
|
$
|
(363
|
)
|
|
$
|
(31
|
)
|
Interest expense
|
|
$
|
(487
|
)
|
|
$
|
(164
|
)
|
|
$
|
(651
|
)
|
Other income
|
|
$
|
31
|
|
|
$
|
8
|
|
|
$
|
39
|
|
Total other expense
|
|
$
|
(452
|
)
|
|
$
|
(156
|
)
|
|
$
|
(608
|
)
|
Loss before income taxes
|
|
$
|
(120
|
)
|
|
$
|
(519
|
)
|
|
$
|
(639
|
)
|
Net income (loss)
|
|
$
|
211
|
|
|
$
|
(519
|
)
|
|
$
|
(308
|
)
|
Net income attributable to noncontrolling interest
|
|
$
|
(2
|
)
|
|
$
|
2
|
|
|
$
|
—
|
|
Net income (loss) attributable to Chesapeake
|
|
$
|
209
|
|
|
$
|
(517
|
)
|
|
$
|
(308
|
)
|
Net income (loss) available to common stockholders
|
|
$
|
101
|
|
|
$
|
(517
|
)
|
|
$
|
(416
|
)
|
Earnings (loss) per common share basic
|
|
$
|
0.06
|
|
|
$
|
(0.31
|
)
|
|
$
|
(0.25
|
)
|
Earnings (loss) per common share diluted
|
|
$
|
0.06
|
|
|
$
|
(0.31
|
)
|
|
$
|
(0.25
|
)
|
|
|
Year Ended December 31, 2018
|
||||||||||
CONSOLIDATED STATEMENTS OF OPERATIONS
|
|
As
Reported Under Full Cost |
|
Adjustment
|
|
As
Reported Under Successful Efforts |
||||||
|
|
($ in millions except per share data)
|
||||||||||
Other revenues
|
|
$
|
—
|
|
|
$
|
63
|
|
|
$
|
63
|
|
Loss on sale of assets
|
|
$
|
—
|
|
|
$
|
(264
|
)
|
|
$
|
(264
|
)
|
Total revenues
|
|
$
|
10,231
|
|
|
$
|
(201
|
)
|
|
$
|
10,030
|
|
Exploration expense
|
|
$
|
—
|
|
|
$
|
162
|
|
|
$
|
162
|
|
General and administrative
|
|
$
|
280
|
|
|
$
|
55
|
|
|
$
|
335
|
|
Depreciation, depletion and amortization
|
|
$
|
1,145
|
|
|
$
|
592
|
|
|
$
|
1,737
|
|
Loss on sale of oil and natural gas properties
|
|
$
|
578
|
|
|
$
|
(578
|
)
|
|
$
|
—
|
|
Impairments
|
|
$
|
53
|
|
|
$
|
78
|
|
|
$
|
131
|
|
Other operating expenses
|
|
$
|
10
|
|
|
$
|
(10
|
)
|
|
$
|
—
|
|
Total operating expenses
|
|
$
|
9,349
|
|
|
$
|
299
|
|
|
$
|
9,648
|
|
Income from operations
|
|
$
|
882
|
|
|
$
|
(500
|
)
|
|
$
|
382
|
|
Interest expense
|
|
$
|
(487
|
)
|
|
$
|
(146
|
)
|
|
$
|
(633
|
)
|
Other income
|
|
$
|
70
|
|
|
$
|
(3
|
)
|
|
$
|
67
|
|
Total other expense
|
|
$
|
(15
|
)
|
|
$
|
(149
|
)
|
|
$
|
(164
|
)
|
Income before income taxes
|
|
$
|
867
|
|
|
$
|
(649
|
)
|
|
$
|
218
|
|
Net income
|
|
$
|
877
|
|
|
$
|
(649
|
)
|
|
$
|
228
|
|
Net income attributable to noncontrolling interest
|
|
$
|
(4
|
)
|
|
$
|
2
|
|
|
$
|
(2
|
)
|
Net income attributable to Chesapeake
|
|
$
|
873
|
|
|
$
|
(647
|
)
|
|
$
|
226
|
|
Earnings allocated to participating securities
|
|
$
|
(6
|
)
|
|
$
|
5
|
|
|
$
|
(1
|
)
|
Net income available to common stockholders
|
|
$
|
775
|
|
|
$
|
(642
|
)
|
|
$
|
133
|
|
Earnings per common share basic
|
|
$
|
0.85
|
|
|
$
|
(0.70
|
)
|
|
$
|
0.15
|
|
Earnings per common share diluted
|
|
$
|
0.85
|
|
|
$
|
(0.70
|
)
|
|
$
|
0.15
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, 2017
|
||||||||||
CONSOLIDATED STATEMENTS OF OPERATIONS
|
|
As
Reported Under Full Cost |
|
Adjustment
|
|
As
Reported Under Successful Efforts |
||||||
|
|
($ in millions except per share data)
|
||||||||||
Other revenues
|
|
$
|
—
|
|
|
$
|
67
|
|
|
$
|
67
|
|
Gain on sales of assets
|
|
$
|
—
|
|
|
$
|
476
|
|
|
$
|
476
|
|
Total revenues
|
|
$
|
9,496
|
|
|
$
|
543
|
|
|
$
|
10,039
|
|
Exploration expense
|
|
$
|
—
|
|
|
$
|
235
|
|
|
$
|
235
|
|
General and administrative
|
|
$
|
262
|
|
|
$
|
71
|
|
|
$
|
333
|
|
Depreciation, depletion and amortization
|
|
$
|
995
|
|
|
$
|
702
|
|
|
$
|
1,697
|
|
Impairments
|
|
$
|
5
|
|
|
$
|
809
|
|
|
$
|
814
|
|
Other operating expenses
|
|
$
|
413
|
|
|
$
|
3
|
|
|
$
|
416
|
|
Total operating expenses
|
|
$
|
8,357
|
|
|
$
|
1,820
|
|
|
$
|
10,177
|
|
Income (loss) from operations
|
|
$
|
1,139
|
|
|
$
|
(1,277
|
)
|
|
$
|
(138
|
)
|
Interest expense
|
|
$
|
(426
|
)
|
|
$
|
(175
|
)
|
|
$
|
(601
|
)
|
Other income
|
|
$
|
9
|
|
|
$
|
(3
|
)
|
|
$
|
6
|
|
Total other expense
|
|
$
|
(184
|
)
|
|
$
|
(178
|
)
|
|
$
|
(362
|
)
|
Income (loss) before income taxes
|
|
$
|
955
|
|
|
$
|
(1,455
|
)
|
|
$
|
(500
|
)
|
Net income (loss)
|
|
$
|
953
|
|
|
$
|
(1,455
|
)
|
|
$
|
(502
|
)
|
Net income attributable to noncontrolling interest
|
|
$
|
(4
|
)
|
|
$
|
1
|
|
|
$
|
(3
|
)
|
Net income (loss) attributable to Chesapeake
|
|
$
|
949
|
|
|
$
|
(1,454
|
)
|
|
$
|
(505
|
)
|
Earnings allocated to participating securities
|
|
$
|
(10
|
)
|
|
$
|
10
|
|
|
$
|
—
|
|
Net income (loss) available to common stockholders
|
|
$
|
813
|
|
|
$
|
(1,444
|
)
|
|
$
|
(631
|
)
|
Earnings (loss) per common share basic
|
|
$
|
0.90
|
|
|
$
|
(1.60
|
)
|
|
$
|
(0.70
|
)
|
Earnings (loss) per common share diluted
|
|
$
|
0.90
|
|
|
$
|
(1.60
|
)
|
|
$
|
(0.70
|
)
|
|
|
Year Ended December 31, 2019
|
||||||||||
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
|
|
Under Full Cost
|
|
Adjustment
|
|
As
Reported Under Successful Efforts |
||||||
|
|
($ in millions except per share data)
|
||||||||||
Net income (loss)
|
|
$
|
211
|
|
|
$
|
(519
|
)
|
|
$
|
(308
|
)
|
Comprehensive income (loss)
|
|
$
|
246
|
|
|
$
|
(519
|
)
|
|
$
|
(273
|
)
|
Comprehensive income attributable to noncontrolling interests
|
|
$
|
(2
|
)
|
|
$
|
2
|
|
|
$
|
—
|
|
Comprehensive income (loss) attributable to Chesapeake
|
|
$
|
244
|
|
|
$
|
(517
|
)
|
|
$
|
(273
|
)
|
|
|
|
|
|
|
|
||||||
|
|
Year Ended December 31, 2018
|
||||||||||
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
|
|
As
Reported Under Full Cost |
|
Adjustment
|
|
As
Reported Under Successful Efforts |
||||||
|
|
($ in millions except per share data)
|
||||||||||
Net income
|
|
$
|
877
|
|
|
$
|
(649
|
)
|
|
$
|
228
|
|
Comprehensive income
|
|
$
|
911
|
|
|
$
|
(649
|
)
|
|
$
|
262
|
|
Comprehensive income attributable to noncontrolling interests
|
|
$
|
(4
|
)
|
|
$
|
2
|
|
|
$
|
(2
|
)
|
Comprehensive income attributable to Chesapeake
|
|
$
|
907
|
|
|
$
|
(647
|
)
|
|
$
|
260
|
|
|
|
|
|
|
|
|
||||||
|
|
Year Ended December 31, 2017
|
||||||||||
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
|
|
As
Reported Under Full Cost |
|
Adjustment
|
|
As
Reported Under Successful Efforts |
||||||
|
|
($ in millions except per share data)
|
||||||||||
Net income (loss)
|
|
$
|
953
|
|
|
$
|
(1,455
|
)
|
|
$
|
(502
|
)
|
Comprehensive income (loss)
|
|
$
|
992
|
|
|
$
|
(1,455
|
)
|
|
$
|
(463
|
)
|
Comprehensive income attributable to noncontrolling interests
|
|
$
|
(4
|
)
|
|
$
|
1
|
|
|
$
|
(3
|
)
|
Comprehensive income (loss) attributable to Chesapeake
|
|
$
|
988
|
|
|
$
|
(1,454
|
)
|
|
$
|
(466
|
)
|
|
|
Year Ended December 31, 2019
|
||||||||||
CONSOLIDATED STATEMENTS OF CASH FLOWS
|
|
Under Full Cost
|
|
Adjustment
|
|
As
Reported Under Successful Efforts |
||||||
|
|
($ in millions except per share data)
|
||||||||||
Net income (loss)
|
|
$
|
211
|
|
|
$
|
(519
|
)
|
|
$
|
(308
|
)
|
Depreciation, depletion and amortization
|
|
$
|
1,616
|
|
|
$
|
648
|
|
|
$
|
2,264
|
|
Gain on sale of oil and gas properties
|
|
$
|
(15
|
)
|
|
$
|
15
|
|
|
$
|
—
|
|
Gain on sales of assets
|
|
$
|
—
|
|
|
$
|
(43
|
)
|
|
$
|
(43
|
)
|
Impairments
|
|
$
|
344
|
|
|
$
|
(333
|
)
|
|
$
|
11
|
|
Exploratory dry hole expense and leasehold impairments
|
|
$
|
—
|
|
|
$
|
49
|
|
|
$
|
49
|
|
Other
|
|
$
|
(2
|
)
|
|
$
|
(2
|
)
|
|
$
|
(4
|
)
|
(Decrease) increase in accounts payable, accrued liabilities and other
|
|
$
|
(567
|
)
|
|
$
|
(63
|
)
|
|
$
|
(630
|
)
|
Net cash provided by operating activities
|
|
$
|
1,871
|
|
|
$
|
(248
|
)
|
|
$
|
1,623
|
|
Drilling and completion costs
|
|
$
|
(2,260
|
)
|
|
$
|
80
|
|
|
$
|
(2,180
|
)
|
Acquisition of proved and unproved properties
|
|
$
|
(203
|
)
|
|
$
|
168
|
|
|
$
|
(35
|
)
|
Net cash used by investing activities
|
|
$
|
(2,728
|
)
|
|
$
|
248
|
|
|
$
|
(2,480
|
)
|
|
|
|
|
|
|
|
||||||
|
|
Year Ended December 31, 2018
|
||||||||||
CONSOLIDATED STATEMENTS OF CASH FLOWS
|
|
As
Reported Under Full Cost |
|
Adjustment
|
|
As
Reported Under Successful Efforts |
||||||
|
|
($ in millions except per share data)
|
||||||||||
Net income
|
|
$
|
877
|
|
|
$
|
(649
|
)
|
|
$
|
228
|
|
Depreciation, depletion and amortization
|
|
$
|
1,145
|
|
|
$
|
592
|
|
|
$
|
1,737
|
|
Loss on sale of oil and gas properties
|
|
$
|
578
|
|
|
$
|
(578
|
)
|
|
$
|
—
|
|
Losses on sales of assets
|
|
$
|
—
|
|
|
$
|
264
|
|
|
$
|
264
|
|
Impairments
|
|
$
|
53
|
|
|
$
|
78
|
|
|
$
|
131
|
|
Exploratory dry hole expense and leasehold impairments
|
|
$
|
—
|
|
|
$
|
96
|
|
|
$
|
96
|
|
Other
|
|
$
|
(108
|
)
|
|
$
|
(10
|
)
|
|
$
|
(118
|
)
|
Increase in accounts payable, accrued liabilities and other
|
|
$
|
138
|
|
|
$
|
(63
|
)
|
|
$
|
75
|
|
Net cash provided by operating activities
|
|
$
|
2,000
|
|
|
$
|
(270
|
)
|
|
$
|
1,730
|
|
Drilling and completion costs
|
|
$
|
(1,958
|
)
|
|
$
|
110
|
|
|
$
|
(1,848
|
)
|
Acquisition of proved and unproved properties
|
|
$
|
(288
|
)
|
|
$
|
160
|
|
|
$
|
(128
|
)
|
Net cash provided by investing activities
|
|
$
|
185
|
|
|
$
|
270
|
|
|
$
|
455
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, 2017
|
||||||||||
CONSOLIDATED STATEMENTS OF CASH FLOWS
|
|
As
Reported Under Full Cost |
|
Adjustment
|
|
As
Reported Under Successful Efforts |
||||||
|
|
($ in millions except per share data)
|
||||||||||
Net income (loss)
|
|
$
|
953
|
|
|
$
|
(1,455
|
)
|
|
$
|
(502
|
)
|
Depreciation, depletion and amortization
|
|
$
|
995
|
|
|
$
|
702
|
|
|
$
|
1,697
|
|
Gains on sales of assets
|
|
$
|
—
|
|
|
$
|
(476
|
)
|
|
$
|
(476
|
)
|
Impairments
|
|
$
|
5
|
|
|
$
|
809
|
|
|
$
|
814
|
|
Exploratory dry hole expense and leasehold impairments
|
|
$
|
—
|
|
|
$
|
214
|
|
|
$
|
214
|
|
Other
|
|
$
|
(135
|
)
|
|
$
|
3
|
|
|
$
|
(132
|
)
|
Decrease in accounts payable, accrued liabilities and other
|
|
$
|
(308
|
)
|
|
$
|
(67
|
)
|
|
$
|
(375
|
)
|
Net cash provided by operating activities
|
|
$
|
745
|
|
|
$
|
(270
|
)
|
|
$
|
475
|
|
Drilling and completion costs
|
|
$
|
(2,186
|
)
|
|
$
|
73
|
|
|
$
|
(2,113
|
)
|
Acquisition of proved and unproved properties
|
|
$
|
(285
|
)
|
|
$
|
197
|
|
|
$
|
(88
|
)
|
Net cash used in investing activities
|
|
$
|
(1,188
|
)
|
|
$
|
270
|
|
|
$
|
(918
|
)
|
|
|
Year Ended December 31, 2019
|
||||||||||
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
|
|
Under Full Cost
|
|
Adjustment
|
|
As
Reported Under Successful Efforts |
||||||
|
|
($ in millions except per share data)
|
||||||||||
Accumulated deficit, beginning of period
|
|
$
|
(15,660
|
)
|
|
$
|
1,748
|
|
|
$
|
(13,912
|
)
|
Net income (loss) attributable to Chesapeake
|
|
$
|
209
|
|
|
$
|
(517
|
)
|
|
$
|
(308
|
)
|
Accumulated deficit, end of period
|
|
$
|
(15,451
|
)
|
|
$
|
1,231
|
|
|
$
|
(14,220
|
)
|
Total Chesapeake stockholders’ equity
|
|
$
|
3,133
|
|
|
$
|
1,231
|
|
|
$
|
4,364
|
|
Noncontrolling interests, beginning of period
|
|
$
|
123
|
|
|
$
|
(82
|
)
|
|
$
|
41
|
|
Net income attributable to noncontrolling interests
|
|
$
|
2
|
|
|
$
|
(2
|
)
|
|
$
|
—
|
|
Noncontrolling interests, end of period
|
|
$
|
121
|
|
|
$
|
(84
|
)
|
|
$
|
37
|
|
Total equity
|
|
$
|
3,254
|
|
|
$
|
1,147
|
|
|
$
|
4,401
|
|
|
|
|
|
|
|
|
||||||
|
|
Year Ended December 31, 2018
|
||||||||||
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
|
|
As
Reported Under Full Cost |
|
Adjustment |
|
As
Reported Under Successful Efforts |
||||||
|
|
($ in millions except per share data)
|
||||||||||
Accumulated deficit, beginning of period
|
|
$
|
(16,525
|
)
|
|
$
|
2,395
|
|
|
$
|
(14,130
|
)
|
Net income attributable to Chesapeake
|
|
$
|
873
|
|
|
$
|
(647
|
)
|
|
$
|
226
|
|
Accumulated deficit, end of period
|
|
$
|
(15,660
|
)
|
|
$
|
1,748
|
|
|
$
|
(13,912
|
)
|
Total Chesapeake stockholders’ equity
|
|
$
|
344
|
|
|
$
|
1,748
|
|
|
$
|
2,092
|
|
Noncontrolling interests, beginning of period
|
|
$
|
124
|
|
|
$
|
(80
|
)
|
|
$
|
44
|
|
Net income attributable to noncontrolling interests
|
|
$
|
4
|
|
|
$
|
(2
|
)
|
|
$
|
2
|
|
Noncontrolling interests, end of period
|
|
$
|
123
|
|
|
$
|
(82
|
)
|
|
$
|
41
|
|
Total equity
|
|
$
|
467
|
|
|
$
|
1,666
|
|
|
$
|
2,133
|
|
|
|
|
|
|
|
|
||||||
|
|
Year Ended December 31, 2017
|
||||||||||
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
|
|
As
Reported Under Full Cost |
|
Adjustment
|
|
As
Reported Under Successful Efforts |
||||||
|
|
($ in millions except per share data)
|
||||||||||
Accumulated deficit, beginning of period
|
|
$
|
(17,474
|
)
|
|
$
|
3,849
|
|
|
$
|
(13,625
|
)
|
Net income (loss) attributable to Chesapeake
|
|
$
|
949
|
|
|
$
|
(1,454
|
)
|
|
$
|
(505
|
)
|
Accumulated deficit, end of period
|
|
$
|
(16,525
|
)
|
|
$
|
2,395
|
|
|
$
|
(14,130
|
)
|
Total Chesapeake stockholders’ equity (deficit)
|
|
$
|
(496
|
)
|
|
$
|
2,395
|
|
|
$
|
1,899
|
|
Noncontrolling interests, beginning of period
|
|
$
|
128
|
|
|
$
|
(79
|
)
|
|
$
|
49
|
|
Net income attributable to noncontrolling interests
|
|
$
|
4
|
|
|
$
|
(1
|
)
|
|
$
|
3
|
|
Noncontrolling interests, end of period
|
|
$
|
124
|
|
|
$
|
(80
|
)
|
|
$
|
44
|
|
Total equity (deficit)
|
|
$
|
(372
|
)
|
|
$
|
2,315
|
|
|
$
|
1,943
|
|
3.
|
Oil and Natural Gas Property Transactions
|
|
Purchase Price Allocation
|
||
|
($ in millions)
|
||
Consideration:
|
|
||
Cash
|
$
|
381
|
|
Fair value of Chesapeake’s common stock issued in the Merger (a)
|
2,037
|
|
|
Total consideration
|
$
|
2,418
|
|
|
|
||
Fair Value of Liabilities Assumed:
|
|
||
Current liabilities
|
$
|
166
|
|
Long-term debt
|
1,379
|
|
|
Deferred tax liabilities
|
314
|
|
|
Other long-term liabilities
|
36
|
|
|
Amounts attributable to liabilities assumed
|
$
|
1,895
|
|
|
|
||
Fair Value of Assets Acquired:
|
|
||
Cash and cash equivalents
|
$
|
28
|
|
Other current assets
|
128
|
|
|
Proved oil and natural gas properties
|
3,264
|
|
|
Unproved properties
|
756
|
|
|
Other property and equipment
|
77
|
|
|
Other long-term assets
|
60
|
|
|
Amounts attributable to assets acquired
|
$
|
4,313
|
|
|
|
||
Total identifiable net assets
|
$
|
2,418
|
|
(a)
|
Based on 717,376,170 Chesapeake common shares issued at closing at $2.84 per share (closing price as of February 1, 2019).
|
|
|
Years Ended
December 31,
|
||||||
|
|
2019
|
|
2018
|
||||
|
|
($ in millions except per share data)
|
||||||
Revenues
|
|
$
|
8,587
|
|
|
$
|
11,211
|
|
Net income (loss) available to common stockholders
|
|
$
|
(431
|
)
|
|
$
|
195
|
|
Earnings (loss) per common share:
|
|
|
|
|
||||
Basic
|
|
$
|
(0.26
|
)
|
|
$
|
0.12
|
|
Diluted
|
|
$
|
(0.26
|
)
|
|
$
|
0.12
|
|
4.
|
Earnings Per Share
|
|
|
Years Ended December 31,
|
|||||||
|
|
2019
|
|
2018
|
|
2017
|
|||
|
|
(in millions)
|
|||||||
Common stock equivalent of our preferred stock outstanding
|
|
58
|
|
|
60
|
|
|
60
|
|
Common stock equivalent of our convertible senior notes outstanding
|
|
124
|
|
|
146
|
|
|
146
|
|
Common stock equivalent of our preferred stock outstanding prior to exchange
|
|
1
|
|
|
—
|
|
|
1
|
|
Participating securities
|
|
—
|
|
|
1
|
|
|
1
|
|
5.
|
Debt
|
|
December 31, 2019
|
|
December 31, 2018
|
||||||||||||
|
Principal
Amount
|
|
Carrying
Amount |
|
Principal
Amount |
|
Carrying
Amount |
||||||||
|
($ in millions)
|
||||||||||||||
Revolving credit facility
|
$
|
1,590
|
|
|
$
|
1,590
|
|
|
$
|
419
|
|
|
$
|
419
|
|
Term loan due 2024
|
1,500
|
|
|
1,470
|
|
|
—
|
|
|
—
|
|
||||
11.5% senior secured second lien notes due 2025
|
2,330
|
|
|
3,248
|
|
|
—
|
|
|
—
|
|
||||
Floating rate senior notes due 2019
|
—
|
|
|
—
|
|
|
380
|
|
|
380
|
|
||||
6.625% senior notes due 2020(a)
|
208
|
|
|
208
|
|
|
437
|
|
|
437
|
|
||||
6.875% senior notes due 2020
|
93
|
|
|
93
|
|
|
227
|
|
|
227
|
|
||||
6.125% senior notes due 2021
|
167
|
|
|
167
|
|
|
548
|
|
|
548
|
|
||||
5.375% senior notes due 2021
|
127
|
|
|
127
|
|
|
267
|
|
|
267
|
|
||||
4.875% senior notes due 2022(a)
|
338
|
|
|
338
|
|
|
451
|
|
|
451
|
|
||||
5.75% senior notes due 2023(a)
|
209
|
|
|
209
|
|
|
338
|
|
|
338
|
|
||||
7.00% senior notes due 2024
|
624
|
|
|
624
|
|
|
850
|
|
|
850
|
|
||||
6.875% senior notes due 2025(b)
|
2
|
|
|
2
|
|
|
—
|
|
|
—
|
|
||||
8.00% senior notes due 2025
|
246
|
|
|
245
|
|
|
1,300
|
|
|
1,291
|
|
||||
5.5% convertible senior notes due 2026(c)(d)(e)
|
1,064
|
|
|
765
|
|
|
1,250
|
|
|
866
|
|
||||
7.5% senior notes due 2026
|
119
|
|
|
119
|
|
|
400
|
|
|
400
|
|
||||
8.00% senior notes due 2026
|
46
|
|
|
44
|
|
|
—
|
|
|
—
|
|
||||
8.00% senior notes due 2027
|
253
|
|
|
253
|
|
|
1,300
|
|
|
1,299
|
|
||||
2.25% contingent convertible senior notes due 2038(c)
|
—
|
|
|
—
|
|
|
1
|
|
|
1
|
|
||||
Debt issuance costs
|
—
|
|
|
(44
|
)
|
|
—
|
|
|
(53
|
)
|
||||
Interest rate derivatives
|
—
|
|
|
—
|
|
|
—
|
|
|
1
|
|
||||
Total debt, net
|
8,916
|
|
|
9,458
|
|
|
8,168
|
|
|
7,722
|
|
||||
Less current maturities of long-term debt, net(f)
|
(385
|
)
|
|
(385
|
)
|
|
(381
|
)
|
|
(381
|
)
|
||||
Total long-term debt, net
|
$
|
8,531
|
|
|
$
|
9,073
|
|
|
$
|
7,787
|
|
|
$
|
7,341
|
|
(a)
|
In December 2019, we entered into a purchase and sale agreement to acquire $101 million principal amount of our 6.625% Senior Notes due 2020, 4.875% Senior Notes due 2022 and 5.75% Senior Notes due 2023. During the first quarter of 2020, we repurchased the senior notes.
|
(b)
|
On February 1, 2019, we acquired the debt of WildHorse which consisted of 6.875% Senior Notes due 2025 and a revolving credit facility and in December 2019 we extinguished the debt with proceeds from a term loan issuance. See further discussion below.
|
(c)
|
We are required to account for the liability and equity components of our convertible debt instruments separately and to reflect interest expense through the first demand repurchase date, as applicable, at the interest rate of similar nonconvertible debt at the time of issuance. The applicable rates for our 5.5% Convertible Senior Notes due 2026 and our 2.25% Contingent Convertible Senior Notes due 2038 are 11.5% and 8.0%, respectively.
|
(d)
|
The conversion and redemption provisions of our convertible senior notes are as follows:
|
(e)
|
The carrying amounts as of December 31, 2019 and 2018, are reflected net of discounts of $299 million and $384 million, respectively, associated with the equity component of our convertible senior notes. This amount is being amortized based on the effective yield method through the first demand repurchase date as applicable.
|
(f)
|
As of December 31, 2019, net current maturities of long-term debt includes our 6.625% Senior Notes due August 2020 and our 6.875% Senior Notes due November 2020. As of December 31, 2018, net current maturities of long-term debt includes our Floating Rate Senior Notes due April 2019 and our 2.25% Contingent Convertible Senior Notes due 2038.
|
|
|
Principal Amount
of Debt Securities
|
||
|
|
($ in millions)
|
||
2020
|
|
$
|
385
|
|
2021
|
|
294
|
|
|
2022
|
|
289
|
|
|
2023
|
|
1,764
|
|
|
2024
|
|
2,124
|
|
|
Thereafter
|
|
4,060
|
|
|
Total
|
|
$
|
8,916
|
|
|
|
Notes Exchanged
|
||
|
|
($ in millions)
|
||
7.00% senior notes due 2024
|
|
$
|
226
|
|
8.00% senior notes due 2025
|
|
999
|
|
|
8.00% senior notes due 2026
|
|
873
|
|
|
7.5% senior notes due 2026
|
|
281
|
|
|
8.00% senior notes due 2027
|
|
837
|
|
|
Total
|
|
$
|
3,216
|
|
|
|
Notes Exchanged
|
||
|
|
($ in millions)
|
||
6.625% senior notes due 2020
|
|
$
|
229
|
|
6.875% senior notes due 2020
|
|
134
|
|
|
6.125% senior notes due 2021
|
|
381
|
|
|
5.375% senior notes due 2021
|
|
140
|
|
|
Total
|
|
$
|
884
|
|
|
|
December 31, 2019
|
|
December 31, 2018
|
||||||||||||
|
|
Carrying
Amount
|
|
Estimated
Fair Value
|
|
Carrying
Amount
|
|
Estimated
Fair Value
|
||||||||
|
|
|
|
($ in millions)
|
|
|
||||||||||
Short-term debt (Level 1)
|
|
$
|
385
|
|
|
$
|
360
|
|
|
$
|
381
|
|
|
$
|
379
|
|
Long-term debt (Level 1)
|
|
$
|
753
|
|
|
$
|
622
|
|
|
$
|
3,495
|
|
|
$
|
3,173
|
|
Long-term debt (Level 2)
|
|
$
|
8,320
|
|
|
$
|
6,085
|
|
|
$
|
3,846
|
|
|
$
|
3,644
|
|
6.
|
Contingencies and Commitments
|
|
|
December 31,
2019 |
||
|
|
($ in millions)
|
||
2020
|
|
$
|
1,136
|
|
2021
|
|
1,033
|
|
|
2022
|
|
913
|
|
|
2023
|
|
789
|
|
|
2024
|
|
690
|
|
|
2025 – 2034
|
|
3,479
|
|
|
Total
|
|
$
|
8,040
|
|
|
|
December 31, 2019
|
||
|
|
($ in millions)
|
||
2020
|
|
$
|
7
|
|
2021
|
|
7
|
|
|
2022
|
|
2
|
|
|
Total
|
|
$
|
16
|
|
7.
|
Other Liabilities
|
|
|
December 31,
|
||||||
|
|
2019
|
|
2018
|
||||
|
|
($ in millions)
|
||||||
Revenues and royalties due others
|
|
$
|
516
|
|
|
$
|
687
|
|
Accrued drilling and production costs
|
|
326
|
|
|
258
|
|
||
Joint interest prepayments received
|
|
52
|
|
|
73
|
|
||
VPP deferred revenue(a)
|
|
55
|
|
|
59
|
|
||
Accrued compensation and benefits
|
|
156
|
|
|
202
|
|
||
Other accrued taxes
|
|
150
|
|
|
108
|
|
||
Other
|
|
177
|
|
|
212
|
|
||
Total other current liabilities
|
|
$
|
1,432
|
|
|
$
|
1,599
|
|
|
|
December 31,
|
||||||
|
|
2019
|
|
2018
|
||||
|
|
($ in millions)
|
||||||
VPP deferred revenue(a)
|
|
$
|
9
|
|
|
$
|
63
|
|
Unrecognized tax benefits(b)
|
|
—
|
|
|
53
|
|
||
Other
|
|
116
|
|
|
103
|
|
||
Total other long-term liabilities
|
|
$
|
125
|
|
|
$
|
219
|
|
(a)
|
At the inception of our volumetric production payment (VPP) agreements, we (i) removed the proved reserves associated with the VPP, (ii) recognized VPP proceeds as deferred revenue which are being amortized on a unit-of-production basis to other revenue over the term of the VPP, (iii) retained responsibility for the production costs and capital costs related to VPP interests and (iv) ceased recognizing production associated with the VPP volumes. The remaining deferred revenue balance will be recognized in other revenues in the consolidated statement of operations through February 2021, assuming the related VPP production volumes are delivered as scheduled.
|
(b)
|
The liability for unrecognized tax benefits was eliminated during the fourth quarter of 2019 as a result of a settlement.
|
8.
|
Leases
|
|
|
Finance
|
|
Operating
|
||||
|
|
($ in millions)
|
||||||
ROU assets
|
|
$
|
17
|
|
|
$
|
22
|
|
|
|
|
|
|
||||
Lease liabilities:
|
|
|
|
|
||||
Current lease liabilities
|
|
$
|
9
|
|
|
$
|
9
|
|
Long-term lease liabilities
|
|
9
|
|
|
16
|
|
||
Total lease liabilities
|
|
$
|
18
|
|
|
$
|
25
|
|
|
|
Year Ended
December 31, 2019 |
||
Lease cost:
|
|
($ in millions)
|
||
Amortization of ROU assets
|
|
$
|
8
|
|
Interest on lease liability
|
|
2
|
|
|
Finance lease cost
|
|
10
|
|
|
Operating lease cost
|
|
26
|
|
|
Short-term lease cost
|
|
112
|
|
|
Total lease cost
|
|
$
|
148
|
|
|
|
|
||
Other information:
|
|
|
||
Operating cash outflows from finance lease
|
|
$
|
2
|
|
Operating cash outflows from operating leases
|
|
$
|
11
|
|
Investing cash outflows from operating leases
|
|
$
|
127
|
|
Financing cash outflows from finance lease
|
|
$
|
8
|
|
|
|
|
||
|
|
|
||
Weighted average remaining lease term - finance lease
|
|
2.00 years
|
|
|
Weighted average remaining lease term - operating leases
|
|
4.65 years
|
|
|
Weighted average discount rate - finance lease
|
|
7.50
|
%
|
|
Weighted average discount rate - operating leases
|
|
4.85
|
%
|
|
|
December 31, 2019
|
||||||
|
|
Finance Lease
|
|
Operating Leases
|
||||
|
|
($ in millions)
|
||||||
2020
|
|
$
|
10
|
|
|
$
|
10
|
|
2021
|
|
10
|
|
|
5
|
|
||
2022
|
|
—
|
|
|
4
|
|
||
2023
|
|
—
|
|
|
2
|
|
||
2024
|
|
—
|
|
|
2
|
|
||
Thereafter
|
|
—
|
|
|
5
|
|
||
Total lease payments
|
|
20
|
|
|
28
|
|
||
Less imputed interest
|
|
(2
|
)
|
|
(3
|
)
|
||
Present value of lease liabilities
|
|
18
|
|
|
25
|
|
||
Less current maturities
|
|
(9
|
)
|
|
(9
|
)
|
||
Present value of lease liabilities, less current maturities
|
|
$
|
9
|
|
|
$
|
16
|
|
|
|
December 31, 2018
|
||||||
|
|
Capital Lease
|
|
Operating Leases
|
||||
|
|
($ in millions)
|
||||||
2019
|
|
$
|
10
|
|
|
$
|
3
|
|
2020
|
|
10
|
|
|
1
|
|
||
2021
|
|
10
|
|
|
—
|
|
||
Total minimum lease payments
|
|
$
|
30
|
|
|
$
|
4
|
|
9.
|
Revenue Recognition
|
|
|
Year Ended December 31, 2019
|
||||||||||||||
|
|
Oil
|
|
Natural Gas
|
|
NGL
|
|
Total
|
||||||||
|
|
($ in millions)
|
||||||||||||||
Marcellus
|
|
$
|
—
|
|
|
$
|
856
|
|
|
$
|
—
|
|
|
$
|
856
|
|
Haynesville
|
|
—
|
|
|
620
|
|
|
—
|
|
|
620
|
|
||||
Eagle Ford
|
|
1,289
|
|
|
153
|
|
|
119
|
|
|
1,561
|
|
||||
Brazos Valley
|
|
721
|
|
|
32
|
|
|
16
|
|
|
769
|
|
||||
Powder River Basin
|
|
369
|
|
|
77
|
|
|
32
|
|
|
478
|
|
||||
Mid-Continent
|
|
164
|
|
|
44
|
|
|
25
|
|
|
233
|
|
||||
Revenue from contracts with customers
|
|
2,543
|
|
|
1,782
|
|
|
192
|
|
|
4,517
|
|
||||
Gains (losses) on oil, natural gas and NGL derivatives
|
|
(212
|
)
|
|
217
|
|
|
—
|
|
|
5
|
|
||||
Oil, natural gas and NGL revenue
|
|
$
|
2,331
|
|
|
$
|
1,999
|
|
|
$
|
192
|
|
|
$
|
4,522
|
|
|
|
|
|
|
|
|
|
|
||||||||
Marketing revenue from contracts with customers
|
|
$
|
2,473
|
|
|
$
|
900
|
|
|
$
|
246
|
|
|
$
|
3,619
|
|
Other marketing revenue
|
|
311
|
|
|
41
|
|
|
—
|
|
|
352
|
|
||||
Losses on marketing derivatives
|
|
—
|
|
|
(4
|
)
|
|
—
|
|
|
(4
|
)
|
||||
Marketing revenue
|
|
$
|
2,784
|
|
|
$
|
937
|
|
|
$
|
246
|
|
|
$
|
3,967
|
|
|
|
|
|
|
|
|
|
|
||||||||
|
|
Year Ended December 31, 2018
|
||||||||||||||
|
|
Oil
|
|
Natural Gas
|
|
NGL
|
|
Total
|
||||||||
|
|
($ in millions)
|
||||||||||||||
Marcellus
|
|
$
|
—
|
|
|
$
|
924
|
|
|
$
|
—
|
|
|
$
|
924
|
|
Haynesville
|
|
2
|
|
|
836
|
|
|
—
|
|
|
838
|
|
||||
Eagle Ford
|
|
1,514
|
|
|
173
|
|
|
185
|
|
|
1,872
|
|
||||
Powder River Basin
|
|
244
|
|
|
68
|
|
|
38
|
|
|
350
|
|
||||
Mid-Continent
|
|
246
|
|
|
84
|
|
|
55
|
|
|
385
|
|
||||
Utica
|
|
195
|
|
|
401
|
|
|
224
|
|
|
820
|
|
||||
Revenue from contracts with customers
|
|
2,201
|
|
|
2,486
|
|
|
502
|
|
|
5,189
|
|
||||
Gains (losses) on oil, natural gas and NGL derivatives
|
|
124
|
|
|
(147
|
)
|
|
(11
|
)
|
|
(34
|
)
|
||||
Oil, natural gas and NGL revenue
|
|
$
|
2,325
|
|
|
$
|
2,339
|
|
|
$
|
491
|
|
|
$
|
5,155
|
|
|
|
|
|
|
|
|
|
|
||||||||
Marketing revenue from contracts with customers
|
|
$
|
2,740
|
|
|
$
|
1,194
|
|
|
$
|
456
|
|
|
$
|
4,390
|
|
Other marketing revenue
|
|
457
|
|
|
222
|
|
|
—
|
|
|
679
|
|
||||
Gains on marketing derivatives
|
|
—
|
|
|
7
|
|
|
—
|
|
|
7
|
|
||||
Marketing revenue
|
|
$
|
3,197
|
|
|
$
|
1,423
|
|
|
$
|
456
|
|
|
$
|
5,076
|
|
|
|
December 31,
|
||||||
|
|
2019
|
|
2018
|
||||
|
|
($ in millions)
|
||||||
Oil, natural gas and NGL sales
|
|
$
|
737
|
|
|
$
|
976
|
|
Joint interest billings
|
|
200
|
|
|
211
|
|
||
Other
|
|
74
|
|
|
77
|
|
||
Allowance for doubtful accounts
|
|
(21
|
)
|
|
(17
|
)
|
||
Total accounts receivable, net
|
|
$
|
990
|
|
|
$
|
1,247
|
|
10.
|
Income Taxes
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Current
|
|
|
|
|
|
|
||||||
Federal
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
(14
|
)
|
State
|
|
(26
|
)
|
|
—
|
|
|
5
|
|
|||
Current Income Taxes
|
|
(26
|
)
|
|
—
|
|
|
(9
|
)
|
|||
Deferred
|
|
|
|
|
|
|
||||||
Federal
|
|
(297
|
)
|
|
3
|
|
|
13
|
|
|||
State
|
|
(8
|
)
|
|
(13
|
)
|
|
(2
|
)
|
|||
Deferred Income Taxes
|
|
(305
|
)
|
|
(10
|
)
|
|
11
|
|
|||
Total
|
|
$
|
(331
|
)
|
|
$
|
(10
|
)
|
|
$
|
2
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Income tax expense (benefit) at the federal statutory rate (21%, 21%, 35%)
|
|
$
|
(134
|
)
|
|
$
|
45
|
|
|
$
|
(175
|
)
|
State income taxes (net of federal income tax benefit)
|
|
(21
|
)
|
|
27
|
|
|
5
|
|
|||
Partial release of valuation allowance due to the WildHorse Merger
|
|
(314
|
)
|
|
—
|
|
|
—
|
|
|||
Remeasurement of deferred tax assets and liabilities
|
|
—
|
|
|
—
|
|
|
931
|
|
|||
Change in valuation allowance excluding impact of WildHorse Merger
|
|
114
|
|
|
(97
|
)
|
|
(771
|
)
|
|||
Other
|
|
24
|
|
|
15
|
|
|
12
|
|
|||
Total
|
|
$
|
(331
|
)
|
|
$
|
(10
|
)
|
|
$
|
2
|
|
|
|
December 31,
|
||||||
|
|
2019
|
|
2018
|
||||
|
|
($ in millions)
|
||||||
Deferred tax liabilities:
|
|
|
|
|
||||
Property, plant and equipment
|
|
$
|
(546
|
)
|
|
$
|
(976
|
)
|
Volumetric production payments
|
|
(89
|
)
|
|
(86
|
)
|
||
Carrying value of debt
|
|
—
|
|
|
(95
|
)
|
||
Derivative instruments
|
|
(14
|
)
|
|
(56
|
)
|
||
Other
|
|
(5
|
)
|
|
(7
|
)
|
||
Deferred tax liabilities
|
|
(654
|
)
|
|
(1,220
|
)
|
||
|
|
|
|
|
||||
Deferred tax assets:
|
|
|
|
|
||||
Net operating loss carryforwards
|
|
1,971
|
|
|
2,737
|
|
||
Carrying value of debt
|
|
169
|
|
|
—
|
|
||
Disallowed business interest carryforward
|
|
25
|
|
|
194
|
|
||
Asset retirement obligations
|
|
50
|
|
|
40
|
|
||
Investments
|
|
83
|
|
|
111
|
|
||
Accrued liabilities
|
|
64
|
|
|
89
|
|
||
Other
|
|
87
|
|
|
60
|
|
||
Deferred tax assets
|
|
2,449
|
|
|
3,231
|
|
||
Valuation allowance
|
|
(1,805
|
)
|
|
(2,011
|
)
|
||
Deferred tax assets after valuation allowance
|
|
644
|
|
|
1,220
|
|
||
Net deferred tax liability
|
|
$
|
(10
|
)
|
|
$
|
—
|
|
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Unrecognized tax benefits at beginning of period
|
|
$
|
79
|
|
|
$
|
106
|
|
|
$
|
202
|
|
Additions based on tax positions related to the current year
|
|
—
|
|
|
—
|
|
|
—
|
|
|||
Additions to tax positions of prior years
|
|
27
|
|
|
—
|
|
|
4
|
|
|||
Settlements
|
|
(32
|
)
|
|
—
|
|
|
(100
|
)
|
|||
Expiration of the applicable statute of limitations
|
|
—
|
|
|
(23
|
)
|
|
—
|
|
|||
Reductions to tax positions of prior years
|
|
—
|
|
|
(4
|
)
|
|
—
|
|
|||
Unrecognized tax benefits at end of period
|
|
$
|
74
|
|
|
$
|
79
|
|
|
$
|
106
|
|
11.
|
Equity
|
|
|
Years Ended December 31,
|
|||||||
|
|
2019
|
|
2018
|
|
2017
|
|||
|
|
(in thousands)
|
|||||||
Shares issued as of January 1
|
|
913,716
|
|
|
908,733
|
|
|
896,279
|
|
Common shares issued for WildHorse Merger(a)
|
|
717,376
|
|
|
—
|
|
|
—
|
|
Exchange of senior notes(b)
|
|
235,564
|
|
|
—
|
|
|
—
|
|
Exchange of convertible notes(b)
|
|
73,389
|
|
|
—
|
|
|
—
|
|
Exchange of preferred stock
|
|
10,368
|
|
|
—
|
|
|
9,966
|
|
Restricted stock issuances (net of forfeitures and cancellations)(c)
|
|
4,146
|
|
|
4,983
|
|
|
2,488
|
|
Shares issued as of December 31
|
|
1,954,559
|
|
|
913,716
|
|
|
908,733
|
|
(a)
|
(b)
|
(c)
|
Preferred Stock Series
|
|
Issue Date
|
|
Liquidation
Preference
per Share
|
|
Holder's Conversion Right
|
|
Conversion Rate
|
|
Conversion Price
|
|
Company's
Conversion
Right From
|
|
Company's Market Conversion Trigger(a)
|
||||||
5.75% cumulative
convertible
non-voting
|
|
May and June 2010
|
|
$
|
1,000
|
|
|
Any time
|
|
39.6858
|
|
$
|
25.1979
|
|
|
May 17, 2015
|
|
$
|
32.7573
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
5.75% (series A)
cumulative
convertible
non-voting
|
|
May 2010
|
|
$
|
1,000
|
|
|
Any time
|
|
38.3508
|
|
$
|
26.0751
|
|
|
May 17, 2015
|
|
$
|
33.8976
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
4.50% cumulative convertible
|
|
September 2005
|
|
$
|
100
|
|
|
Any time
|
|
2.4561
|
|
$
|
40.7152
|
|
|
September 15, 2010
|
|
$
|
52.9298
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
5.00% cumulative convertible (series 2005B)
|
|
November 2005
|
|
$
|
100
|
|
|
Any time
|
|
2.7745
|
|
$
|
36.0431
|
|
|
November 15, 2010
|
|
$
|
46.8560
|
|
(a)
|
Convertible at the Company's option if the trading price of the Company's common stock equals or exceeds the trigger price for a specified time period or after the applicable conversion date if there are less than 250,000 shares of 4.50% or 5.00% (Series 2005B) preferred stock outstanding or 25,000 shares of 5.75% or 5.75% (Series A) preferred stock outstanding.
|
|
|
5.75%
|
|
5.75% (Series A)
|
|
4.50%
|
|
5.00%
(Series 2005B)
|
||||
|
|
(in thousands)
|
||||||||||
Shares outstanding as of January 1, 2019
|
|
770
|
|
|
463
|
|
|
2,559
|
|
|
1,811
|
|
Preferred stock exchanges(a)
|
|
—
|
|
|
(40
|
)
|
|
—
|
|
|
—
|
|
Shares outstanding as of December 31, 2019
|
|
770
|
|
|
423
|
|
|
2,559
|
|
|
1,811
|
|
|
|
|
|
|
|
|
|
|
||||
Shares outstanding as of January 1, 2018
and December 31, 2018 |
|
770
|
|
|
463
|
|
|
2,559
|
|
|
1,811
|
|
|
|
|
|
|
|
|
|
|
||||
Shares outstanding as of January 1, 2017
|
|
843
|
|
|
476
|
|
|
2,559
|
|
|
1,962
|
|
Preferred stock exchanges(b)
|
|
(73
|
)
|
|
(13
|
)
|
|
—
|
|
|
(151
|
)
|
Shares outstanding as of December 31, 2017
|
|
770
|
|
|
463
|
|
|
2,559
|
|
|
1,811
|
|
(a)
|
During 2019, we exchanged 10,367,950 shares of common stock for 40,000 shares of our 5.75% (Series A) Cumulative Convertible Preferred Stock. In connection with the exchange, we recognized a loss equal to the excess of the fair value of all common stock issued in exchange for the preferred stock over the fair value of the common stock issuable pursuant to the original terms of the preferred stock. The loss of $17 million is reflected as a reduction to net income available to common stockholders for the purpose of calculating earnings per common share.
|
(b)
|
During 2017, holders of our 5.75% Cumulative Convertible Preferred Stock exchanged 72,600 shares into 7,442,156 shares of common stock, holders of our 5.75% (Series A) Cumulative Convertible Preferred Stock exchanged 12,500 shares into 1,205,923 shares of common stock and holders of our 5.00% (Series 2005B) Cumulative Convertible Preferred Stock exchanged 150,948 shares into 1,317,756 shares of common stock. In connection with the exchanges, we recognized a loss equal to the excess of the fair value of all common stock issued in exchange for the preferred stock over the fair value of the common stock issuable pursuant to the original terms of the preferred stock. The loss of $41 million is reflected as a reduction to net income available to common stockholders for the purpose of calculating earnings per common share.
|
|
|
Years Ended December 31,
|
||||||
|
|
2019
|
|
2018
|
||||
|
|
($ in millions)
|
||||||
Balance, as of January 1
|
|
$
|
(23
|
)
|
|
$
|
(57
|
)
|
Amounts reclassified from accumulated other comprehensive income(a)
|
|
35
|
|
|
34
|
|
||
Balance, as of December 31
|
|
$
|
12
|
|
|
$
|
(23
|
)
|
(a)
|
Net losses on cash flow hedges for commodity contracts reclassified from accumulated other comprehensive income (loss), net of tax, to oil, natural gas and NGL revenues in the consolidated statements of operations.
|
12.
|
Share-Based Compensation
|
|
|
Shares of
Unvested
Restricted Stock
|
|
Weighted Average
Grant Date
Fair Value
|
|||
|
|
(in thousands)
|
|
|
|||
Unvested restricted stock as of January 1, 2019
|
|
11,858
|
|
|
$
|
4.43
|
|
Granted
|
|
5,908
|
|
|
$
|
2.65
|
|
Vested
|
|
(5,944
|
)
|
|
$
|
4.38
|
|
Forfeited
|
|
(1,380
|
)
|
|
$
|
3.72
|
|
Unvested restricted stock as of December 31, 2019
|
|
10,442
|
|
|
$
|
3.55
|
|
|
|
|
|
|
|||
Unvested restricted stock as of January 1, 2018
|
|
13,178
|
|
|
$
|
6.37
|
|
Granted
|
|
6,067
|
|
|
$
|
3.73
|
|
Vested
|
|
(5,808
|
)
|
|
$
|
7.67
|
|
Forfeited
|
|
(1,579
|
)
|
|
$
|
6.02
|
|
Unvested restricted stock as of December 31, 2018
|
|
11,858
|
|
|
$
|
4.43
|
|
|
|
|
|
|
|||
Unvested restricted stock as of January 1, 2017
|
|
9,092
|
|
|
$
|
11.39
|
|
Granted
|
|
9,872
|
|
|
$
|
5.40
|
|
Vested
|
|
(4,573
|
)
|
|
$
|
13.73
|
|
Forfeited
|
|
(1,213
|
)
|
|
$
|
8.32
|
|
Unvested restricted stock as of December 31, 2017
|
|
13,178
|
|
|
$
|
6.37
|
|
Expected option life – years
|
|
6.0
|
|
Volatility
|
|
65.61
|
%
|
Risk-free interest rate
|
|
2.47
|
%
|
Dividend yield
|
|
—
|
%
|
|
|
Number of
Shares
Underlying
Options
|
|
Weighted
Average
Exercise Price Per Share
|
|
Weighted
Average
Contract Life in Years
|
|
Aggregate
Intrinsic
Value(a)
|
|||||
|
|
(in thousands)
|
|
|
|
|
|
($ in millions)
|
|||||
Outstanding as of January 1, 2019
|
|
18,096
|
|
|
$
|
7.20
|
|
|
7.15
|
|
$
|
—
|
|
Granted
|
|
1,000
|
|
|
$
|
2.97
|
|
|
|
|
|
||
Exercised
|
|
—
|
|
|
$
|
—
|
|
|
|
|
$
|
—
|
|
Expired
|
|
(553
|
)
|
|
$
|
6.36
|
|
|
|
|
|
||
Forfeited
|
|
(609
|
)
|
|
$
|
3.97
|
|
|
|
|
|
||
Outstanding as of December 31, 2019
|
|
17,934
|
|
|
$
|
7.10
|
|
|
5.70
|
|
$
|
—
|
|
Exercisable as of December 31, 2019
|
|
13,092
|
|
|
$
|
8.28
|
|
|
4.86
|
|
$
|
—
|
|
|
|
|
|
|
|
|
|
|
|||||
Outstanding as of January 1, 2018
|
|
16,285
|
|
|
$
|
8.25
|
|
|
7.73
|
|
$
|
1
|
|
Granted
|
|
3,611
|
|
|
$
|
3.01
|
|
|
|
|
|
||
Exercised
|
|
—
|
|
|
$
|
—
|
|
|
|
|
$
|
—
|
|
Expired
|
|
(602
|
)
|
|
$
|
13.83
|
|
|
|
|
|
||
Forfeited
|
|
(1,198
|
)
|
|
$
|
5.45
|
|
|
|
|
|
||
Outstanding as of December 31, 2018
|
|
18,096
|
|
|
$
|
7.20
|
|
|
7.15
|
|
$
|
—
|
|
Exercisable as of December 31, 2018
|
|
8,250
|
|
|
$
|
10.73
|
|
|
5.73
|
|
$
|
—
|
|
|
|
|
|
|
|
|
|
|
|||||
Outstanding as of January 1, 2017
|
|
8,593
|
|
|
$
|
11.88
|
|
|
7.22
|
|
$
|
14
|
|
Granted
|
|
9,226
|
|
|
$
|
5.45
|
|
|
|
|
|
||
Exercised
|
|
—
|
|
|
$
|
—
|
|
|
|
|
$
|
—
|
|
Expired
|
|
(435
|
)
|
|
$
|
18.50
|
|
|
|
|
|
||
Forfeited
|
|
(1,099
|
)
|
|
$
|
9.12
|
|
|
|
|
|
||
Outstanding as of December 31, 2017
|
|
16,285
|
|
|
$
|
8.25
|
|
|
7.73
|
|
$
|
1
|
|
Exercisable as of December 31, 2017
|
|
4,474
|
|
|
$
|
15.15
|
|
|
5.26
|
|
$
|
—
|
|
(a)
|
The intrinsic value of a stock option is the amount by which the current market value or the market value upon exercise of the underlying stock exceeds the exercise price of the option.
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
General and administrative expenses
|
|
$
|
26
|
|
|
$
|
31
|
|
|
$
|
43
|
|
Oil and natural gas properties
|
|
2
|
|
|
2
|
|
|
5
|
|
|||
Oil, natural gas and NGL production expenses
|
|
3
|
|
|
5
|
|
|
12
|
|
|||
Exploration expenses
|
|
1
|
|
|
1
|
|
|
1
|
|
|||
Total restricted stock and stock option compensation
|
|
$
|
32
|
|
|
$
|
39
|
|
|
$
|
61
|
|
|
|
|
|
Grant Date
Fair Value
|
|
December 31, 2019
|
|||||||||
|
|
Units
|
|
|
Fair Value
|
|
Vested Liability
|
||||||||
|
|
|
|
($ in millions)
|
|
($ in millions)
|
|||||||||
2019 PSU Awards:
|
|
|
|
|
|
|
|
|
|||||||
Payable 2020, 2021 and 2022
|
|
4,674,503
|
|
|
$
|
14
|
|
|
$
|
4
|
|
|
$
|
—
|
|
2018 PSU Awards:
|
|
|
|
|
|
|
|
|
|||||||
Payable 2020 and 2021
|
|
2,340,157
|
|
|
$
|
7
|
|
|
$
|
2
|
|
|
$
|
—
|
|
2017 PSU Awards:
|
|
|
|
|
|
|
|
|
|||||||
Payable 2020
|
|
1,174,973
|
|
|
$
|
8
|
|
|
$
|
1
|
|
|
$
|
—
|
|
2018 CRSU Awards:
|
|
|
|
|
|
|
|
|
|||||||
Payable 2020 and 2021
|
|
8,233,207
|
|
|
$
|
25
|
|
|
$
|
7
|
|
|
$
|
—
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
General and administrative expenses
|
|
$
|
5
|
|
|
$
|
9
|
|
|
$
|
(4
|
)
|
Oil and natural gas properties
|
|
1
|
|
|
1
|
|
|
—
|
|
|||
Oil, natural gas and NGL production expenses
|
|
3
|
|
|
2
|
|
|
—
|
|
|||
Restructuring and other termination costs
|
|
1
|
|
|
—
|
|
|
—
|
|
|||
Total liability-classified awards compensation
|
|
$
|
10
|
|
|
$
|
12
|
|
|
$
|
(4
|
)
|
14.
|
Derivative and Hedging Activities
|
•
|
Swaps: We receive a fixed price and pay a floating market price to the counterparty for the hedged commodity. In exchange for higher fixed prices on certain of our swap trades, we may sell call options and call swaptions.
|
•
|
Options: We sell, and occasionally buy, call options in exchange for a premium. At the time of settlement, if the market price exceeds the fixed price of the call option, we pay the counterparty the excess on sold call options and we receive the excess on bought call options. If the market price settles below the fixed price of the call option, no payment is due from either party.
|
•
|
Call Swaptions: We sell call swaptions to counterparties in exchange for a premium. Swaptions allow the counterparty, on a specific date, to extend an existing fixed-price swap for a certain period of time or to increase the notional volumes of an existing fixed-price swap.
|
•
|
Collars: These instruments contain a fixed floor price (put) and ceiling price (call). If the market price exceeds the call strike price or falls below the put strike price, we receive the fixed price and pay the market price. If the market price is between the put and the call strike prices, no payments are due from either party. Three-way collars include the sale by us of an additional put option in exchange for a more favorable strike price on the call option. This eliminates the counterparty’s downside exposure below the second put option strike price.
|
•
|
Basis Protection Swaps: These instruments are arrangements that guarantee a fixed price differential to NYMEX from a specified delivery point. We receive the fixed price differential and pay the floating market price differential to the counterparty for the hedged commodity.
|
|
|
December 31, 2019
|
|
December 31, 2018
|
||||||||||
|
|
Notional Volume
|
|
Fair Value
|
|
Notional Volume
|
|
Fair Value
|
||||||
|
|
|
|
($ in millions)
|
|
|
|
($ in millions)
|
||||||
Oil (mmbbl):
|
|
|
|
|
|
|
|
|
||||||
Fixed-price swaps
|
|
24
|
|
|
$
|
(7
|
)
|
|
12
|
|
|
$
|
157
|
|
Collars
|
|
2
|
|
|
14
|
|
|
8
|
|
|
98
|
|
||
Basis protection swaps
|
|
8
|
|
|
(2
|
)
|
|
7
|
|
|
5
|
|
||
Total oil
|
|
34
|
|
|
5
|
|
|
27
|
|
|
260
|
|
||
Natural gas (bcf):
|
|
|
|
|
|
|
|
|
||||||
Fixed-price swaps
|
|
265
|
|
|
125
|
|
|
623
|
|
|
26
|
|
||
Three-way collars
|
|
—
|
|
|
—
|
|
|
88
|
|
|
1
|
|
||
Collars
|
|
—
|
|
|
—
|
|
|
55
|
|
|
(3
|
)
|
||
Call options
|
|
22
|
|
|
—
|
|
|
44
|
|
|
—
|
|
||
Call swaptions
|
|
29
|
|
|
(2
|
)
|
|
106
|
|
|
(9
|
)
|
||
Basis protection swaps
|
|
30
|
|
|
2
|
|
|
50
|
|
|
—
|
|
||
Total natural gas
|
|
346
|
|
|
125
|
|
|
966
|
|
|
15
|
|
||
Contingent Consideration:
|
|
|
|
|
|
|
|
|
||||||
Utica divestiture
|
|
|
|
—
|
|
|
|
|
7
|
|
||||
Total estimated fair value
|
|
|
|
$
|
130
|
|
|
|
|
$
|
282
|
|
Balance Sheet Classification
|
|
Gross
Fair Value
|
|
Amounts Netted
in the
Consolidated
Balance Sheets
|
|
Net Fair Value
Presented in the
Consolidated
Balance Sheets
|
||||||
|
|
($ in millions)
|
||||||||||
As of December 31, 2019
|
|
|
|
|
|
|
||||||
Commodity Contracts:
|
|
|
|
|
|
|
||||||
Short-term derivative asset
|
|
$
|
174
|
|
|
$
|
(40
|
)
|
|
$
|
134
|
|
Short-term derivative liability
|
|
(42
|
)
|
|
40
|
|
|
(2
|
)
|
|||
Long-term derivative liability
|
|
(2
|
)
|
|
—
|
|
|
(2
|
)
|
|||
Total derivatives
|
|
$
|
130
|
|
|
$
|
—
|
|
|
$
|
130
|
|
|
|
|
|
|
|
|
||||||
As of December 31, 2018
|
|
|
|
|
|
|
||||||
Commodity Contracts:
|
|
|
|
|
|
|
||||||
Short-term derivative asset
|
|
$
|
306
|
|
|
$
|
(104
|
)
|
|
$
|
202
|
|
Long-term derivative asset
|
|
117
|
|
|
(41
|
)
|
|
76
|
|
|||
Short-term derivative liability
|
|
(107
|
)
|
|
104
|
|
|
(3
|
)
|
|||
Long-term derivative liability
|
|
(41
|
)
|
|
41
|
|
|
—
|
|
|||
Contingent Consideration:
|
|
|
|
|
|
|
||||||
Short-term derivative asset
|
|
7
|
|
|
—
|
|
|
7
|
|
|||
Total derivatives
|
|
$
|
282
|
|
|
$
|
—
|
|
|
$
|
282
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Oil, natural gas and NGL revenues
|
|
$
|
4,517
|
|
|
$
|
5,189
|
|
|
$
|
4,574
|
|
Gains on undesignated oil, natural gas and NGL derivatives
|
|
40
|
|
|
—
|
|
|
445
|
|
|||
Losses on terminated cash flow hedges
|
|
(35
|
)
|
|
(34
|
)
|
|
(34
|
)
|
|||
Total oil, natural gas and NGL revenues
|
|
$
|
4,522
|
|
|
$
|
5,155
|
|
|
$
|
4,985
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Marketing revenues
|
|
$
|
3,971
|
|
|
$
|
5,069
|
|
|
$
|
4,511
|
|
Gains (losses) on undesignated marketing natural gas derivatives
|
|
(4
|
)
|
|
7
|
|
|
—
|
|
|||
Total marketing revenues
|
|
$
|
3,967
|
|
|
$
|
5,076
|
|
|
$
|
4,511
|
|
|
|
Years Ended December 31,
|
||||||||||||||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||||||||||||||
|
|
Before
Tax |
|
After
Tax |
|
Before
Tax |
|
After
Tax |
|
Before
Tax |
|
After
Tax |
||||||||||||
|
|
($ in millions)
|
||||||||||||||||||||||
Balance, beginning of period
|
|
$
|
(80
|
)
|
|
$
|
(23
|
)
|
|
$
|
(114
|
)
|
|
$
|
(57
|
)
|
|
$
|
(153
|
)
|
|
$
|
(96
|
)
|
Net change in fair value
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
5
|
|
|
5
|
|
||||||
Losses reclassified to income
|
|
35
|
|
|
35
|
|
|
34
|
|
|
34
|
|
|
34
|
|
|
34
|
|
||||||
Balance, end of period
|
|
$
|
(45
|
)
|
|
$
|
12
|
|
|
$
|
(80
|
)
|
|
$
|
(23
|
)
|
|
$
|
(114
|
)
|
|
$
|
(57
|
)
|
|
|
Quoted
Prices in
Active
Markets
(Level 1)
|
|
Significant
Other
Observable
Inputs
(Level 2)
|
|
Significant
Unobservable
Inputs
(Level 3)
|
|
Total
Fair Value
|
||||||||
|
|
|
|
($ in millions)
|
|
|
||||||||||
As of December 31, 2019
|
|
|
|
|
|
|
|
|
||||||||
Derivative Assets (Liabilities):
|
|
|
|
|
|
|
|
|
||||||||
Commodity assets
|
|
$
|
—
|
|
|
$
|
160
|
|
|
$
|
14
|
|
|
$
|
174
|
|
Commodity liabilities
|
|
—
|
|
|
(42
|
)
|
|
(2
|
)
|
|
(44
|
)
|
||||
Total derivatives
|
|
$
|
—
|
|
|
$
|
118
|
|
|
$
|
12
|
|
|
$
|
130
|
|
|
|
|
|
|
|
|
|
|
||||||||
As of December 31, 2018
|
|
|
|
|
|
|
|
|
||||||||
Derivative Assets (Liabilities):
|
|
|
|
|
|
|
|
|
||||||||
Commodity assets
|
|
$
|
—
|
|
|
$
|
319
|
|
|
$
|
103
|
|
|
$
|
422
|
|
Commodity liabilities
|
|
—
|
|
|
(131
|
)
|
|
(16
|
)
|
|
(147
|
)
|
||||
Utica divestiture contingent consideration
|
|
—
|
|
|
—
|
|
|
7
|
|
|
7
|
|
||||
Total derivatives
|
|
$
|
—
|
|
|
$
|
188
|
|
|
$
|
94
|
|
|
$
|
282
|
|
|
|
Commodity
Derivatives
|
|
Utica Contingent Consideration
|
||||
|
|
($ in millions)
|
||||||
Balance, as of January 1, 2019
|
|
$
|
87
|
|
|
$
|
7
|
|
Total gains (losses) (realized/unrealized):
|
|
|
|
|
||||
Included in earnings(a)
|
|
(59
|
)
|
|
(7
|
)
|
||
Total purchases, issuances, sales and settlements:
|
|
|
|
|
||||
Settlements
|
|
(16
|
)
|
|
—
|
|
||
Balance, as of December 31, 2019
|
|
$
|
12
|
|
|
$
|
—
|
|
|
|
|
|
|
||||
Balance, as of January 1, 2018
|
|
$
|
(15
|
)
|
|
$
|
—
|
|
Total gains (losses) (realized/unrealized):
|
|
|
|
|
||||
Included in earnings(a)
|
|
77
|
|
|
7
|
|
||
Total purchases, issuances, sales and settlements:
|
|
|
|
|
||||
Settlements
|
|
25
|
|
|
—
|
|
||
Balance, as of December 31, 2018
|
|
$
|
87
|
|
|
$
|
7
|
|
(a)
|
|
|
Commodity Derivatives
|
|
Utica Contingent Consideration
|
||||||||||||
|
|
||||||||||||||||
|
|
|
2019
|
|
2018
|
|
2019
|
|
2018
|
||||||||
|
|
|
($ in millions)
|
||||||||||||||
|
Total gains (losses) included in earnings for the period
|
|
$
|
(59
|
)
|
|
$
|
77
|
|
|
$
|
(7
|
)
|
|
$
|
7
|
|
|
Change in unrealized gains (losses) related to assets
still held at reporting date
|
|
$
|
(19
|
)
|
|
$
|
86
|
|
|
$
|
—
|
|
|
$
|
7
|
|
Instrument
Type
|
|
Unobservable
Input
|
|
Range
|
|
Weighted
Average
|
|
Fair Value
December 31, 2019 |
||
|
|
|
|
|
|
|
|
($ in millions)
|
||
Oil trades
|
|
Oil price volatility curves
|
|
20.71% – 67.28%
|
|
25.62%
|
|
$
|
14
|
|
Natural gas trades
|
|
Natural gas price volatility
curves
|
|
16.93% – 171.49%
|
|
39.67%
|
|
$
|
(2
|
)
|
15.
|
Fair Value Measurements
|
|
|
Quoted
Prices in
Active
Markets
(Level 1)
|
|
Significant
Other
Observable
Inputs
(Level 2)
|
|
Significant
Unobservable
Inputs
(Level 3)
|
|
Total
Fair Value
|
||||||||
|
|
($ in millions)
|
||||||||||||||
As of December 31, 2019
|
|
|
|
|
|
|
|
|
||||||||
Financial Assets (Liabilities):
|
|
|
|
|
|
|
|
|
||||||||
Other current assets
|
|
$
|
42
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
42
|
|
Other current liabilities
|
|
(43
|
)
|
|
—
|
|
|
—
|
|
|
(43
|
)
|
||||
Total
|
|
$
|
(1
|
)
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
(1
|
)
|
|
|
|
|
|
|
|
|
|
||||||||
As of December 31, 2018
|
|
|
|
|
|
|
|
|
||||||||
Financial Assets (Liabilities):
|
|
|
|
|
|
|
|
|
||||||||
Other current assets
|
|
$
|
50
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
50
|
|
Other current liabilities
|
|
(51
|
)
|
|
—
|
|
|
—
|
|
|
(51
|
)
|
||||
Total
|
|
$
|
(1
|
)
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
(1
|
)
|
16.
|
Capitalized Exploratory Well Costs
|
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
(in millions)
|
||||||||||
Balance as of January 1
|
|
$
|
36
|
|
|
$
|
36
|
|
|
$
|
41
|
|
Additions pending the determination of proved reserves
|
|
7
|
|
|
74
|
|
|
14
|
|
|||
Divestitures and other
|
|
(3
|
)
|
|
—
|
|
|
—
|
|
|||
Reclassifications to proved properties
|
|
(17
|
)
|
|
(40
|
)
|
|
(19
|
)
|
|||
Charges to exploration expense
|
|
(16
|
)
|
|
(34
|
)
|
|
—
|
|
|||
Balance as of December 31
|
|
$
|
7
|
|
|
$
|
36
|
|
|
$
|
36
|
|
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
(in millions)
|
||||||||||
Exploratory well costs capitalized for a period of one year or less
|
|
$
|
7
|
|
|
$
|
34
|
|
|
$
|
4
|
|
Exploratory well costs capitalized for a period greater than one year
|
|
—
|
|
|
2
|
|
|
32
|
|
|||
Balance as of December 31
|
|
$
|
7
|
|
|
$
|
36
|
|
|
$
|
36
|
|
|
|
|
|
|
|
|
||||||
Number of projects with exploratory well costs capitalized for a period greater than one year
|
|
—
|
|
|
7
|
|
|
6
|
|
17.
|
Other Property and Equipment
|
|
|
December 31,
|
|
Estimated
Useful
Life
|
||||||
|
|
2019
|
|
2018
|
|
|||||
|
|
($ in millions)
|
|
(in years)
|
||||||
Buildings and improvements
|
|
$
|
1,058
|
|
|
$
|
1,053
|
|
|
10 – 39
|
Computer equipment
|
|
355
|
|
|
353
|
|
|
5
|
||
Sand mine
|
|
78
|
|
|
—
|
|
|
10 – 30
|
||
Natural gas compressors(a)
|
|
48
|
|
|
48
|
|
|
3 – 20
|
||
Land
|
|
115
|
|
|
106
|
|
|
|
||
Other
|
|
156
|
|
|
161
|
|
|
5 – 20
|
||
Total other property and equipment, at cost
|
|
1,810
|
|
|
1,721
|
|
|
|
||
Less: accumulated depreciation
|
|
(692
|
)
|
|
(630
|
)
|
|
|
||
Total other property and equipment, net
|
|
$
|
1,118
|
|
|
$
|
1,091
|
|
|
|
(a)
|
Includes assets under finance lease of $27 million, less accumulated depreciation of $10 million and $1 million, as of December 31, 2019 and 2018, respectively. The related amortization expense for assets under finance lease is included in depreciation, depletion and amortization expense on our consolidated statement of operations.
|
18.
|
Investments
|
19.
|
Impairments
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Impairments due to lower forecasted commodity prices
|
|
$
|
8
|
|
|
$
|
23
|
|
|
$
|
27
|
|
Impairments due to reduction in future development(a)
|
|
—
|
|
|
—
|
|
|
560
|
|
|||
Impairments due to anticipated sale
|
|
—
|
|
|
55
|
|
|
222
|
|
|||
Total impairments of oil and natural gas properties
|
|
$
|
8
|
|
|
$
|
78
|
|
|
$
|
809
|
|
(a)
|
The impairment was the result of an updated development plan in 2017, which included a removal of PUDs from properties in the process of being divested in the Mid-Continent operating area.
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Natural gas compressors(a)
|
|
$
|
—
|
|
|
$
|
45
|
|
|
$
|
—
|
|
Buildings and land
|
|
1
|
|
|
4
|
|
|
5
|
|
|||
Other
|
|
2
|
|
|
4
|
|
|
—
|
|
|||
Total impairments of fixed assets and other
|
|
$
|
3
|
|
|
$
|
53
|
|
|
$
|
5
|
|
(a)
|
In 2018, we recorded a $45 million impairment related to 890 compressors for the difference between carrying value and the fair value of the assets.
|
20.
|
Other Operating Expense
|
21.
|
Restructuring and Other Termination Costs
|
22.
|
Asset Retirement Obligations
|
|
|
Years Ended December 31,
|
||||||
|
|
2019
|
|
2018
|
||||
|
|
($ in millions)
|
||||||
Asset retirement obligations, beginning of period
|
|
$
|
166
|
|
|
$
|
177
|
|
Additions(a)
|
|
21
|
|
|
3
|
|
||
Revisions
|
|
18
|
|
|
11
|
|
||
Settlements and disposals
|
|
(5
|
)
|
|
(35
|
)
|
||
Accretion expense
|
|
11
|
|
|
10
|
|
||
Asset retirement obligations, end of period
|
|
211
|
|
|
166
|
|
||
Less current portion
|
|
11
|
|
|
11
|
|
||
Asset retirement obligation, long-term
|
|
$
|
200
|
|
|
$
|
155
|
|
(a)
|
During 2019, approximately $17 million of additions relate to the acquisition of WildHorse.
|
23.
|
Major Customers
|
24.
|
Related Party Transactions
|
25.
|
Condensed Consolidating Financial Information
|
|
|
Parent
|
|
Guarantor
Subsidiaries
|
|
Non-Guarantor
Subsidiaries
|
|
Eliminations
|
|
Consolidated
|
||||||||||
CURRENT ASSETS:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Cash and cash equivalents
|
|
$
|
16
|
|
|
$
|
1
|
|
|
$
|
5
|
|
|
$
|
(16
|
)
|
|
$
|
6
|
|
Other current assets
|
|
51
|
|
|
1,090
|
|
|
104
|
|
|
—
|
|
|
1,245
|
|
|||||
Intercompany receivable, net
|
|
7,702
|
|
|
—
|
|
|
—
|
|
|
(7,702
|
)
|
|
—
|
|
|||||
Total Current Assets
|
|
7,769
|
|
|
1,091
|
|
|
109
|
|
|
(7,718
|
)
|
|
1,251
|
|
|||||
PROPERTY AND EQUIPMENT:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Oil and natural gas properties at cost,
based on successful efforts accounting, net
|
|
—
|
|
|
9,440
|
|
|
4,188
|
|
|
—
|
|
|
13,628
|
|
|||||
Other property and equipment, net
|
|
—
|
|
|
1,030
|
|
|
88
|
|
|
—
|
|
|
1,118
|
|
|||||
Property and equipment
held for sale, net
|
|
—
|
|
|
10
|
|
|
—
|
|
|
—
|
|
|
10
|
|
|||||
Total Property and Equipment,
Net
|
|
—
|
|
|
10,480
|
|
|
4,276
|
|
|
—
|
|
|
14,756
|
|
|||||
LONG-TERM ASSETS:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Other long-term assets
|
|
41
|
|
|
125
|
|
|
19
|
|
|
1
|
|
|
186
|
|
|||||
Investments in subsidiaries and
intercompany advances
|
|
6,101
|
|
|
4,171
|
|
|
—
|
|
|
(10,272
|
)
|
|
—
|
|
|||||
TOTAL ASSETS
|
|
$
|
13,911
|
|
|
$
|
15,867
|
|
|
$
|
4,404
|
|
|
$
|
(17,989
|
)
|
|
$
|
16,193
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
CURRENT LIABILITIES:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Current liabilities
|
|
$
|
466
|
|
|
$
|
1,765
|
|
|
$
|
176
|
|
|
$
|
(15
|
)
|
|
$
|
2,392
|
|
Intercompany payable, net
|
|
—
|
|
|
7,702
|
|
|
—
|
|
|
(7,702
|
)
|
|
—
|
|
|||||
Total Current Liabilities
|
|
466
|
|
|
9,467
|
|
|
176
|
|
|
(7,717
|
)
|
|
2,392
|
|
|||||
LONG-TERM LIABILITIES:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Long-term debt, net
|
|
9,071
|
|
|
—
|
|
|
2
|
|
|
—
|
|
|
9,073
|
|
|||||
Deferred income tax liabilities
|
|
10
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
10
|
|
|||||
Other long-term liabilities
|
|
—
|
|
|
299
|
|
|
18
|
|
|
—
|
|
|
317
|
|
|||||
Total Long-Term Liabilities
|
|
9,081
|
|
|
299
|
|
|
20
|
|
|
—
|
|
|
9,400
|
|
|||||
EQUITY:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Chesapeake stockholders’ equity
|
|
4,364
|
|
|
6,101
|
|
|
4,171
|
|
|
(10,272
|
)
|
|
4,364
|
|
|||||
Noncontrolling interests
|
|
—
|
|
|
—
|
|
|
37
|
|
|
—
|
|
|
37
|
|
|||||
Total Equity
|
|
4,364
|
|
|
6,101
|
|
|
4,208
|
|
|
(10,272
|
)
|
|
4,401
|
|
|||||
TOTAL LIABILITIES AND EQUITY
|
|
$
|
13,911
|
|
|
$
|
15,867
|
|
|
$
|
4,404
|
|
|
$
|
(17,989
|
)
|
|
$
|
16,193
|
|
|
|
Parent
|
|
Guarantor
Subsidiaries
|
|
Non-Guarantor
Subsidiaries
|
|
Eliminations
|
|
Consolidated
|
||||||||||
CURRENT ASSETS:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Cash and cash equivalents
|
|
$
|
4
|
|
|
$
|
1
|
|
|
$
|
1
|
|
|
$
|
(2
|
)
|
|
$
|
4
|
|
Other current assets
|
|
60
|
|
|
1,532
|
|
|
2
|
|
|
—
|
|
|
1,594
|
|
|||||
Intercompany receivable, net
|
|
6,671
|
|
|
—
|
|
|
—
|
|
|
(6,671
|
)
|
|
—
|
|
|||||
Total Current Assets
|
|
6,735
|
|
|
1,533
|
|
|
3
|
|
|
(6,673
|
)
|
|
1,598
|
|
|||||
PROPERTY AND EQUIPMENT:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Oil and natural gas properties at cost, based on successful efforts accounting, net
|
|
—
|
|
|
9,664
|
|
|
48
|
|
|
—
|
|
|
9,712
|
|
|||||
Other property and equipment, net
|
|
—
|
|
|
1,091
|
|
|
—
|
|
|
—
|
|
|
1,091
|
|
|||||
Property and equipment
held for sale, net
|
|
—
|
|
|
15
|
|
|
—
|
|
|
—
|
|
|
15
|
|
|||||
Total Property and Equipment, Net
|
|
—
|
|
|
10,770
|
|
|
48
|
|
|
—
|
|
|
10,818
|
|
|||||
LONG-TERM ASSETS:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Other long-term assets
|
|
26
|
|
|
293
|
|
|
—
|
|
|
—
|
|
|
319
|
|
|||||
Investments in subsidiaries and
intercompany advances
|
|
3,248
|
|
|
9
|
|
|
—
|
|
|
(3,257
|
)
|
|
—
|
|
|||||
TOTAL ASSETS
|
|
$
|
10,009
|
|
|
$
|
12,605
|
|
|
$
|
51
|
|
|
$
|
(9,930
|
)
|
|
$
|
12,735
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
CURRENT LIABILITIES:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Current liabilities
|
|
$
|
523
|
|
|
$
|
2,365
|
|
|
$
|
1
|
|
|
$
|
(2
|
)
|
|
$
|
2,887
|
|
Intercompany payable, net
|
|
—
|
|
|
6,671
|
|
|
—
|
|
|
(6,671
|
)
|
|
—
|
|
|||||
Total Current Liabilities
|
|
523
|
|
|
9,036
|
|
|
1
|
|
|
(6,673
|
)
|
|
2,887
|
|
|||||
LONG-TERM LIABILITIES:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Long-term debt, net
|
|
7,341
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
7,341
|
|
|||||
Other long-term liabilities
|
|
53
|
|
|
321
|
|
|
—
|
|
|
—
|
|
|
374
|
|
|||||
Total Long-Term Liabilities
|
|
7,394
|
|
|
321
|
|
|
—
|
|
|
—
|
|
|
7,715
|
|
|||||
EQUITY:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Chesapeake stockholders’ equity
|
|
2,092
|
|
|
3,248
|
|
|
9
|
|
|
(3,257
|
)
|
|
2,092
|
|
|||||
Noncontrolling interests
|
|
—
|
|
|
—
|
|
|
41
|
|
|
—
|
|
|
41
|
|
|||||
Total Equity
|
|
2,092
|
|
|
3,248
|
|
|
50
|
|
|
(3,257
|
)
|
|
2,133
|
|
|||||
TOTAL LIABILITIES AND EQUITY
|
|
$
|
10,009
|
|
|
$
|
12,605
|
|
|
$
|
51
|
|
|
$
|
(9,930
|
)
|
|
$
|
12,735
|
|
|
|
Parent
|
|
Guarantor
Subsidiaries
|
|
Non-
Guarantor
Subsidiaries
|
|
Eliminations
|
|
Consolidated
|
||||||||||
REVENUES AND OTHER:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Oil, natural gas and NGL
|
|
$
|
—
|
|
|
$
|
3,760
|
|
|
$
|
762
|
|
|
$
|
—
|
|
|
$
|
4,522
|
|
Marketing
|
|
—
|
|
|
3,967
|
|
|
—
|
|
|
—
|
|
|
3,967
|
|
|||||
Total Revenues
|
|
—
|
|
|
7,727
|
|
|
762
|
|
|
—
|
|
|
8,489
|
|
|||||
Other
|
|
—
|
|
|
60
|
|
|
3
|
|
|
—
|
|
|
63
|
|
|||||
Gains on sales of assets
|
|
—
|
|
|
43
|
|
|
—
|
|
|
—
|
|
|
43
|
|
|||||
Total Revenues and Other
|
|
—
|
|
|
7,830
|
|
|
765
|
|
|
—
|
|
|
8,595
|
|
|||||
OPERATING EXPENSES:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Oil, natural gas and NGL production
|
|
—
|
|
|
436
|
|
|
84
|
|
|
—
|
|
|
520
|
|
|||||
Oil, natural gas and NGL gathering, processing and transportation
|
|
—
|
|
|
1,062
|
|
|
20
|
|
|
—
|
|
|
1,082
|
|
|||||
Severance and ad valorem taxes
|
|
—
|
|
|
174
|
|
|
50
|
|
|
—
|
|
|
224
|
|
|||||
Exploration
|
|
—
|
|
|
77
|
|
|
7
|
|
|
—
|
|
|
84
|
|
|||||
Marketing
|
|
—
|
|
|
4,003
|
|
|
—
|
|
|
—
|
|
|
4,003
|
|
|||||
General and administrative
|
|
1
|
|
|
237
|
|
|
77
|
|
|
—
|
|
|
315
|
|
|||||
Restructuring and other termination costs
|
|
—
|
|
|
12
|
|
|
—
|
|
|
—
|
|
|
12
|
|
|||||
Provision for legal contingencies, net
|
|
—
|
|
|
19
|
|
|
—
|
|
|
—
|
|
|
19
|
|
|||||
Depreciation, depletion and amortization
|
|
—
|
|
|
1,719
|
|
|
545
|
|
|
—
|
|
|
2,264
|
|
|||||
Impairments
|
|
—
|
|
|
11
|
|
|
—
|
|
|
—
|
|
|
11
|
|
|||||
Other operating expense
|
|
—
|
|
|
52
|
|
|
40
|
|
|
—
|
|
|
92
|
|
|||||
Total Operating Expenses
|
|
1
|
|
|
7,802
|
|
|
823
|
|
|
—
|
|
|
8,626
|
|
|||||
INCOME (LOSS) FROM OPERATIONS
|
|
(1
|
)
|
|
28
|
|
|
(58
|
)
|
|
—
|
|
|
(31
|
)
|
|||||
OTHER INCOME (EXPENSE):
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Interest income (expense)
|
|
(598
|
)
|
|
16
|
|
|
(69
|
)
|
|
—
|
|
|
(651
|
)
|
|||||
Losses on investments
|
|
—
|
|
|
(47
|
)
|
|
(24
|
)
|
|
—
|
|
|
(71
|
)
|
|||||
Gains on purchases or exchanges of debt
|
|
65
|
|
|
—
|
|
|
10
|
|
|
—
|
|
|
75
|
|
|||||
Other income
|
|
—
|
|
|
39
|
|
|
—
|
|
|
—
|
|
|
39
|
|
|||||
Equity in net earnings (losses) of subsidiary
|
|
(105
|
)
|
|
(141
|
)
|
|
—
|
|
|
246
|
|
|
—
|
|
|||||
Total Other Expense
|
|
(638
|
)
|
|
(133
|
)
|
|
(83
|
)
|
|
246
|
|
|
(608
|
)
|
|||||
LOSS BEFORE INCOME TAXES
|
|
(639
|
)
|
|
(105
|
)
|
|
(141
|
)
|
|
246
|
|
|
(639
|
)
|
|||||
INCOME TAX BENEFIT
|
|
(331
|
)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(331
|
)
|
|||||
NET LOSS
|
|
(308
|
)
|
|
(105
|
)
|
|
(141
|
)
|
|
246
|
|
|
(308
|
)
|
|||||
Net income attributable to
noncontrolling interests
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||
NET LOSS ATTRIBUTABLE
TO CHESAPEAKE
|
|
(308
|
)
|
|
(105
|
)
|
|
(141
|
)
|
|
246
|
|
|
(308
|
)
|
|||||
Other comprehensive income
|
|
—
|
|
|
35
|
|
|
—
|
|
|
—
|
|
|
35
|
|
|||||
COMPREHENSIVE LOSS
ATTRIBUTABLE TO CHESAPEAKE
|
|
$
|
(308
|
)
|
|
$
|
(70
|
)
|
|
$
|
(141
|
)
|
|
$
|
246
|
|
|
$
|
(273
|
)
|
|
|
Parent
|
|
Guarantor
Subsidiaries
|
|
Non-
Guarantor
Subsidiaries
|
|
Eliminations
|
|
Consolidated
|
||||||||||
REVENUES AND OTHER:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Oil, natural gas and NGL
|
|
$
|
—
|
|
|
$
|
5,136
|
|
|
$
|
19
|
|
|
$
|
—
|
|
|
$
|
5,155
|
|
Marketing
|
|
—
|
|
|
5,076
|
|
|
—
|
|
|
—
|
|
|
5,076
|
|
|||||
Total Revenues
|
|
—
|
|
|
10,212
|
|
|
19
|
|
|
—
|
|
|
10,231
|
|
|||||
Other
|
|
—
|
|
|
63
|
|
|
—
|
|
|
—
|
|
|
63
|
|
|||||
Losses on sales of assets
|
|
—
|
|
|
(264
|
)
|
|
—
|
|
|
—
|
|
|
(264
|
)
|
|||||
Total Revenues and Other
|
|
—
|
|
|
10,011
|
|
|
19
|
|
|
—
|
|
|
10,030
|
|
|||||
OPERATING EXPENSES:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Oil, natural gas and NGL production
|
|
—
|
|
|
474
|
|
|
—
|
|
|
—
|
|
|
474
|
|
|||||
Oil, natural gas and NGL gathering, processing and transportation
|
|
—
|
|
|
1,391
|
|
|
7
|
|
|
—
|
|
|
1,398
|
|
|||||
Severance and ad valorem taxes
|
|
—
|
|
|
188
|
|
|
1
|
|
|
—
|
|
|
189
|
|
|||||
Exploration
|
|
—
|
|
|
162
|
|
|
—
|
|
|
—
|
|
|
162
|
|
|||||
Marketing
|
|
—
|
|
|
5,158
|
|
|
—
|
|
|
—
|
|
|
5,158
|
|
|||||
General and administrative
|
|
2
|
|
|
332
|
|
|
1
|
|
|
—
|
|
|
335
|
|
|||||
Restructuring and other termination costs
|
|
—
|
|
|
38
|
|
|
—
|
|
|
—
|
|
|
38
|
|
|||||
Provision for legal contingencies, net
|
|
—
|
|
|
26
|
|
|
—
|
|
|
—
|
|
|
26
|
|
|||||
Depreciation, depletion and amortization
|
|
—
|
|
|
1,730
|
|
|
7
|
|
|
—
|
|
|
1,737
|
|
|||||
Impairments
|
|
—
|
|
|
131
|
|
|
—
|
|
|
—
|
|
|
131
|
|
|||||
Total Operating Expenses
|
|
2
|
|
|
9,630
|
|
|
16
|
|
|
—
|
|
|
9,648
|
|
|||||
INCOME (LOSS) FROM OPERATIONS
|
|
(2
|
)
|
|
381
|
|
|
3
|
|
|
—
|
|
|
382
|
|
|||||
OTHER INCOME (EXPENSE):
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Interest expense
|
|
(631
|
)
|
|
(2
|
)
|
|
—
|
|
|
—
|
|
|
(633
|
)
|
|||||
Gains on investments
|
|
—
|
|
|
139
|
|
|
—
|
|
|
—
|
|
|
139
|
|
|||||
Gains on purchases or exchanges of debt
|
|
263
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
263
|
|
|||||
Other income
|
|
3
|
|
|
64
|
|
|
—
|
|
|
—
|
|
|
67
|
|
|||||
Equity in net earnings of subsidiary
|
|
583
|
|
|
1
|
|
|
—
|
|
|
(584
|
)
|
|
—
|
|
|||||
Total Other Income (Expense)
|
|
218
|
|
|
202
|
|
|
—
|
|
|
(584
|
)
|
|
(164
|
)
|
|||||
INCOME BEFORE INCOME TAXES
|
|
216
|
|
|
583
|
|
|
3
|
|
|
(584
|
)
|
|
218
|
|
|||||
INCOME TAX BENEFIT
|
|
(10
|
)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(10
|
)
|
|||||
NET INCOME
|
|
226
|
|
|
583
|
|
|
3
|
|
|
(584
|
)
|
|
228
|
|
|||||
Net income attributable to
noncontrolling interests
|
|
—
|
|
|
—
|
|
|
(2
|
)
|
|
—
|
|
|
(2
|
)
|
|||||
NET INCOME ATTRIBUTABLE
TO CHESAPEAKE
|
|
226
|
|
|
583
|
|
|
1
|
|
|
(584
|
)
|
|
226
|
|
|||||
Other comprehensive income
|
|
—
|
|
|
34
|
|
|
—
|
|
|
—
|
|
|
34
|
|
|||||
COMPREHENSIVE INCOME
ATTRIBUTABLE TO CHESAPEAKE
|
|
$
|
226
|
|
|
$
|
617
|
|
|
$
|
1
|
|
|
$
|
(584
|
)
|
|
$
|
260
|
|
|
|
Parent
|
|
Guarantor
Subsidiaries
|
|
Non-
Guarantor
Subsidiaries
|
|
Eliminations
|
|
Consolidated
|
||||||||||
REVENUES AND OTHER:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Oil, natural gas and NGL
|
|
$
|
—
|
|
|
$
|
4,962
|
|
|
$
|
23
|
|
|
$
|
—
|
|
|
$
|
4,985
|
|
Marketing
|
|
—
|
|
|
4,511
|
|
|
—
|
|
|
—
|
|
|
4,511
|
|
|||||
Total Revenues
|
|
—
|
|
|
9,473
|
|
|
23
|
|
|
—
|
|
|
9,496
|
|
|||||
Other
|
|
—
|
|
|
67
|
|
|
—
|
|
|
—
|
|
|
67
|
|
|||||
Gains on sales of assets
|
|
—
|
|
|
476
|
|
|
—
|
|
|
—
|
|
|
476
|
|
|||||
Total Revenues and Other
|
|
—
|
|
|
10,016
|
|
|
23
|
|
|
—
|
|
|
10,039
|
|
|||||
OPERATING EXPENSES:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Oil, natural gas and NGL production
|
|
—
|
|
|
517
|
|
|
—
|
|
|
—
|
|
|
517
|
|
|||||
Oil, natural gas and NGL gathering, processing and transportation
|
|
—
|
|
|
1,463
|
|
|
8
|
|
|
—
|
|
|
1,471
|
|
|||||
Severance and ad valorem taxes
|
|
—
|
|
|
133
|
|
|
1
|
|
|
—
|
|
|
134
|
|
|||||
Exploration
|
|
—
|
|
|
235
|
|
|
—
|
|
|
—
|
|
|
235
|
|
|||||
Marketing
|
|
—
|
|
|
4,598
|
|
|
—
|
|
|
—
|
|
|
4,598
|
|
|||||
General and administrative
|
|
1
|
|
|
330
|
|
|
2
|
|
|
—
|
|
|
333
|
|
|||||
Provision for legal contingencies, net
|
|
(79
|
)
|
|
41
|
|
|
—
|
|
|
—
|
|
|
(38
|
)
|
|||||
Depreciation, depletion and amortization
|
|
—
|
|
|
1,688
|
|
|
9
|
|
|
—
|
|
|
1,697
|
|
|||||
Impairments
|
|
—
|
|
|
814
|
|
|
—
|
|
|
—
|
|
|
814
|
|
|||||
Other operating expense
|
|
—
|
|
|
416
|
|
|
—
|
|
|
—
|
|
|
416
|
|
|||||
Total Operating (Income) Expenses
|
|
(78
|
)
|
|
10,235
|
|
|
20
|
|
|
—
|
|
|
10,177
|
|
|||||
INCOME (LOSS) FROM OPERATIONS
|
|
78
|
|
|
(219
|
)
|
|
3
|
|
|
—
|
|
|
(138
|
)
|
|||||
OTHER INCOME (EXPENSE):
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Interest expense
|
|
(599
|
)
|
|
(2
|
)
|
|
—
|
|
|
—
|
|
|
(601
|
)
|
|||||
Gains on purchases or exchanges of debt
|
|
233
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
233
|
|
|||||
Other income
|
|
1
|
|
|
5
|
|
|
—
|
|
|
—
|
|
|
6
|
|
|||||
Equity in net losses of subsidiary
|
|
(216
|
)
|
|
—
|
|
|
—
|
|
|
216
|
|
|
—
|
|
|||||
Total Other Income (Expense)
|
|
(581
|
)
|
|
3
|
|
|
—
|
|
|
216
|
|
|
(362
|
)
|
|||||
INCOME (LOSS) BEFORE INCOME TAXES
|
|
(503
|
)
|
|
(216
|
)
|
|
3
|
|
|
216
|
|
|
(500
|
)
|
|||||
INCOME TAX EXPENSE
|
|
2
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
2
|
|
|||||
NET INCOME (LOSS)
|
|
(505
|
)
|
|
(216
|
)
|
|
3
|
|
|
216
|
|
|
(502
|
)
|
|||||
Net income attributable to
noncontrolling interests
|
|
—
|
|
|
—
|
|
|
(3
|
)
|
|
—
|
|
|
(3
|
)
|
|||||
NET LOSS ATTRIBUTABLE
TO CHESAPEAKE
|
|
(505
|
)
|
|
(216
|
)
|
|
—
|
|
|
216
|
|
|
(505
|
)
|
|||||
Other comprehensive income
|
|
—
|
|
|
39
|
|
|
—
|
|
|
—
|
|
|
39
|
|
|||||
COMPREHENSIVE LOSS
ATTRIBUTABLE TO CHESAPEAKE
|
|
$
|
(505
|
)
|
|
$
|
(177
|
)
|
|
$
|
—
|
|
|
$
|
216
|
|
|
$
|
(466
|
)
|
26.
|
Subsequent Events
|
|
|
2019
First Quarter
|
|
2019
Second Quarter
|
|
2019
Third Quarter
|
|
2019
Fourth Quarter
|
||||||||
|
|
($ in millions except per share data)
|
||||||||||||||
Total revenues
|
|
$
|
2,196
|
|
|
$
|
2,386
|
|
|
$
|
2,087
|
|
|
$
|
1,926
|
|
Income (loss) from operations
|
|
$
|
(182
|
)
|
|
$
|
278
|
|
|
$
|
46
|
|
|
$
|
(173
|
)
|
Net income (loss) attributable to
Chesapeake
|
|
$
|
(21
|
)
|
|
$
|
98
|
|
|
$
|
(61
|
)
|
|
$
|
(324
|
)
|
Net income (loss) available to common stockholders
|
|
$
|
(44
|
)
|
|
$
|
75
|
|
|
$
|
(101
|
)
|
|
$
|
(346
|
)
|
|
|
|
|
|
|
|
|
|
||||||||
Net income (loss) per common share:
|
|
|
|
|
|
|
|
|
||||||||
Basic
|
|
$
|
(0.03
|
)
|
|
$
|
0.05
|
|
|
$
|
(0.06
|
)
|
|
$
|
(0.18
|
)
|
Diluted
|
|
$
|
(0.03
|
)
|
|
$
|
0.05
|
|
|
$
|
(0.06
|
)
|
|
$
|
(0.18
|
)
|
|
|
2018
First Quarter
|
|
2018
Second Quarter
|
|
2018
Third Quarter
|
|
2018
Fourth Quarter
|
||||||||
|
|
($ in millions except per share data)
|
||||||||||||||
Total revenues
|
|
$
|
2,524
|
|
|
$
|
2,289
|
|
|
$
|
2,424
|
|
|
$
|
2,793
|
|
Income (loss) from operations
|
|
$
|
42
|
|
|
$
|
(160
|
)
|
|
$
|
82
|
|
|
$
|
418
|
|
Net income (loss) attributable to
Chesapeake
|
|
$
|
17
|
|
|
$
|
(249
|
)
|
|
$
|
(146
|
)
|
|
$
|
604
|
|
Net income (loss) available to common stockholders
|
|
$
|
(6
|
)
|
|
$
|
(272
|
)
|
|
$
|
(169
|
)
|
|
$
|
576
|
|
|
|
|
|
|
|
|
|
|
||||||||
Net income (loss) per common share:
|
|
|
|
|
|
|
|
|
||||||||
Basic
|
|
$
|
(0.01
|
)
|
|
$
|
(0.30
|
)
|
|
$
|
(0.19
|
)
|
|
$
|
0.63
|
|
Diluted
|
|
$
|
(0.01
|
)
|
|
$
|
(0.30
|
)
|
|
$
|
(0.19
|
)
|
|
$
|
0.57
|
|
|
|
December 31,
|
||||||
|
|
2019
|
|
2018
|
||||
|
|
($ in millions)
|
||||||
Oil and oil and natural gas properties:
|
|
|
|
|
||||
Proved
|
|
$
|
30,765
|
|
|
$
|
25,407
|
|
Unproved
|
|
2,173
|
|
|
1,561
|
|
||
Total
|
|
32,938
|
|
|
26,968
|
|
||
Less accumulated depreciation, depletion and amortization
|
|
(19,310
|
)
|
|
(17,256
|
)
|
||
Net capitalized costs
|
|
$
|
13,628
|
|
|
$
|
9,712
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Acquisition of Properties(a):
|
|
|
|
|
|
|
||||||
Proved properties
|
|
$
|
3,264
|
|
|
$
|
80
|
|
|
$
|
23
|
|
Unproved properties
|
|
792
|
|
|
56
|
|
|
74
|
|
|||
Exploratory costs
|
|
42
|
|
|
80
|
|
|
22
|
|
|||
Development costs
|
|
2,177
|
|
|
1,954
|
|
|
2,075
|
|
|||
Costs incurred
|
|
$
|
6,275
|
|
|
$
|
2,170
|
|
|
$
|
2,194
|
|
(a)
|
Includes $3.264 billion and $756 million of proved and unproved property acquisitions, respectively, related to our acquisition of WildHorse in 2019.
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Oil, natural gas and NGL sales
|
|
$
|
4,522
|
|
|
$
|
5,155
|
|
|
$
|
4,985
|
|
Other revenue
|
|
63
|
|
|
63
|
|
|
67
|
|
|||
Oil, natural gas and NGL production expenses
|
|
(520
|
)
|
|
(474
|
)
|
|
(517
|
)
|
|||
Oil, natural gas and NGL gathering, processing and
transportation expenses
|
|
(1,082
|
)
|
|
(1,398
|
)
|
|
(1,471
|
)
|
|||
Severance and ad valorem taxes
|
|
(224
|
)
|
|
(189
|
)
|
|
(134
|
)
|
|||
Exploration
|
|
(84
|
)
|
|
(162
|
)
|
|
(235
|
)
|
|||
Depletion and depreciation
|
|
(2,188
|
)
|
|
(1,665
|
)
|
|
(1,615
|
)
|
|||
Impairment of oil and natural gas properties
|
|
(8
|
)
|
|
(78
|
)
|
|
(809
|
)
|
|||
Imputed income tax provision(a)
|
|
(125
|
)
|
|
(326
|
)
|
|
(107
|
)
|
|||
Results of operations from oil, natural gas and NGL producing
activities |
|
$
|
354
|
|
|
$
|
926
|
|
|
$
|
164
|
|
(a)
|
The imputed income tax provision is hypothetical (at the statutory tax rate) and determined without regard to our deduction for general and administrative expenses, interest costs and other income tax credits and deductions, nor whether the hypothetical tax provision (benefit) will be payable (receivable).
|
|
|
Oil
|
|
Natural Gas
|
|
NGL
|
|
Total
|
||||
|
|
(mmbbl)
|
|
(bcf)
|
|
(mmbbl)
|
|
(mmboe)
|
||||
December 31, 2019
|
|
|
|
|
|
|
|
|
||||
Proved reserves, beginning of period
|
|
215.5
|
|
|
6,777
|
|
|
103.3
|
|
|
1,448
|
|
Extensions, discoveries and other additions
|
|
52.2
|
|
|
897
|
|
|
13.9
|
|
|
216
|
|
Revisions of previous estimates
|
|
(40.9
|
)
|
|
(516
|
)
|
|
(15.8
|
)
|
|
(143
|
)
|
Production
|
|
(43.0
|
)
|
|
(728
|
)
|
|
(12.3
|
)
|
|
(177
|
)
|
Sale of reserves-in-place
|
|
(1.8
|
)
|
|
(23
|
)
|
|
(1.4
|
)
|
|
(7
|
)
|
Purchase of reserves-in-place
|
|
176.0
|
|
|
159
|
|
|
32.3
|
|
|
235
|
|
Proved reserves, end of period
|
|
358.0
|
|
|
6,566
|
|
|
120.0
|
|
|
1,572
|
|
Proved developed reserves:
|
|
|
|
|
|
|
|
|
||||
Beginning of period
|
|
127.6
|
|
|
3,314
|
|
|
67.9
|
|
|
748
|
|
End of period
|
|
201.4
|
|
|
3,377
|
|
|
82.1
|
|
|
846
|
|
Proved undeveloped reserves:
|
|
|
|
|
|
|
|
|
||||
Beginning of period
|
|
87.9
|
|
|
3,463
|
|
|
35.4
|
|
|
700
|
|
End of period(a)
|
|
156.6
|
|
|
3,189
|
|
|
37.9
|
|
|
726
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil
|
|
Natural Gas
|
|
NGL
|
|
Total
|
||||
|
|
(mmbbl)
|
|
(bcf)
|
|
(mmbbl)
|
|
(mmboe)
|
||||
December 31, 2018
|
|
|
|
|
|
|
|
|
||||
Proved reserves, beginning of period
|
|
260.2
|
|
|
8,600
|
|
|
218.6
|
|
|
1,912
|
|
Extensions, discoveries and other additions
|
|
56.3
|
|
|
1,162
|
|
|
19.8
|
|
|
270
|
|
Revisions of previous estimates
|
|
(30.5
|
)
|
|
242
|
|
|
5.4
|
|
|
15
|
|
Production
|
|
(32.7
|
)
|
|
(832
|
)
|
|
(18.9
|
)
|
|
(190
|
)
|
Sale of reserves-in-place
|
|
(37.8
|
)
|
|
(2,395
|
)
|
|
(121.6
|
)
|
|
(559
|
)
|
Purchase of reserves-in-place
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
Proved reserves, end of period
|
|
215.5
|
|
|
6,777
|
|
|
103.3
|
|
|
1,448
|
|
Proved developed reserves:
|
|
|
|
|
|
|
|
|
||||
Beginning of period
|
|
150.9
|
|
|
4,980
|
|
|
135.0
|
|
|
1,116
|
|
End of period
|
|
127.6
|
|
|
3,314
|
|
|
67.9
|
|
|
748
|
|
Proved undeveloped reserves:
|
|
|
|
|
|
|
|
|
||||
Beginning of period
|
|
109.3
|
|
|
3,620
|
|
|
83.6
|
|
|
796
|
|
End of period(a)
|
|
87.9
|
|
|
3,463
|
|
|
35.4
|
|
|
700
|
|
|
|
|
|
|
|
|
|
|
||||
December 31, 2017
|
|
|
|
|
|
|
|
|
||||
Proved reserves, beginning of period
|
|
399.1
|
|
|
6,496
|
|
|
226.4
|
|
|
1,708
|
|
Extensions, discoveries and other additions
|
|
62.7
|
|
|
3,694
|
|
|
44.9
|
|
|
723
|
|
Revisions of previous estimates
|
|
(168.1
|
)
|
|
(315
|
)
|
|
(31.0
|
)
|
|
(252
|
)
|
Production
|
|
(32.7
|
)
|
|
(878
|
)
|
|
(20.9
|
)
|
|
(200
|
)
|
Sale of reserves-in-place
|
|
(0.9
|
)
|
|
(418
|
)
|
|
(0.8
|
)
|
|
(71
|
)
|
Purchase of reserves-in-place
|
|
0.1
|
|
|
21
|
|
|
—
|
|
|
4
|
|
Proved reserves, end of period
|
|
260.2
|
|
|
8,600
|
|
|
218.6
|
|
|
1,912
|
|
Proved developed reserves:
|
|
|
|
|
|
|
|
|
||||
Beginning of period
|
|
200.4
|
|
|
5,126
|
|
|
134.2
|
|
|
1,189
|
|
End of period
|
|
150.9
|
|
|
4,980
|
|
|
135.0
|
|
|
1,116
|
|
Proved undeveloped reserves:
|
|
|
|
|
|
|
|
|
||||
Beginning of period
|
|
198.7
|
|
|
1,370
|
|
|
92.2
|
|
|
519
|
|
End of period(a)
|
|
109.3
|
|
|
3,620
|
|
|
83.6
|
|
|
796
|
|
(a)
|
As of December 31, 2019, 2018 and 2017, there were no PUDs that had remained undeveloped for five years or more.
|
|
|
Years Ended December 31,
|
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
|
||||||
|
|
($ in millions)
|
|
||||||||||
Future cash inflows
|
|
$
|
29,857
|
|
(a)
|
$
|
27,312
|
|
(b)
|
$
|
26,412
|
|
(c)
|
Future production costs
|
|
(6,956
|
)
|
|
(5,946
|
)
|
|
(7,044
|
)
|
|
|||
Future development costs
|
|
(5,757
|
)
|
|
(4,032
|
)
|
|
(4,977
|
)
|
|
|||
Future income tax provisions
|
|
(75
|
)
|
|
(331
|
)
|
|
—
|
|
|
|||
Future net cash flows
|
|
17,069
|
|
|
17,003
|
|
|
14,391
|
|
|
|||
Less effect of a 10% discount factor
|
|
(8,069
|
)
|
|
(7,508
|
)
|
|
(6,901
|
)
|
|
|||
Standardized measure of discounted future net cash flows(d)
|
|
$
|
9,000
|
|
|
$
|
9,495
|
|
|
$
|
7,490
|
|
|
(a)
|
Calculated using prices of $55.69 per bbl of oil and $2.58 per mcf of natural gas, before field differentials.
|
(b)
|
Calculated using prices of $65.56 per bbl of oil and $3.10 per mcf of natural gas, before field differentials.
|
(c)
|
Calculated using prices of $51.34 per bbl of oil and $2.98 per mcf of natural gas, before field differentials.
|
(d)
|
Excludes discounted future net cash inflows attributable to production volumes sold to VPP buyers. See Note 7.
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2019
|
|
2018
|
|
2017
|
||||||
|
|
($ in millions)
|
||||||||||
Standardized measure, beginning of period(a)
|
|
$
|
9,495
|
|
|
$
|
7,490
|
|
|
$
|
4,379
|
|
Sales of oil and natural gas produced, net of production costs and gathering, processing and transportation(b)
|
|
(2,691
|
)
|
|
(3,128
|
)
|
|
(2,452
|
)
|
|||
Net changes in prices and production costs
|
|
(3,457
|
)
|
|
3,317
|
|
|
3,977
|
|
|||
Extensions and discoveries, net of production and
development costs
|
|
991
|
|
|
1,666
|
|
|
1,951
|
|
|||
Changes in estimated future development costs
|
|
366
|
|
|
1,113
|
|
|
614
|
|
|||
Previously estimated development costs incurred during the period
|
|
775
|
|
|
973
|
|
|
775
|
|
|||
Revisions of previous quantity estimates
|
|
(793
|
)
|
|
47
|
|
|
(1,255
|
)
|
|||
Purchase of reserves-in-place
|
|
3,435
|
|
|
—
|
|
|
3
|
|
|||
Sales of reserves-in-place
|
|
(57
|
)
|
|
(2,052
|
)
|
|
(116
|
)
|
|||
Accretion of discount
|
|
953
|
|
|
749
|
|
|
441
|
|
|||
Net change in income taxes
|
|
17
|
|
|
(32
|
)
|
|
26
|
|
|||
Changes in production rates and other
|
|
(34
|
)
|
|
(648
|
)
|
|
(853
|
)
|
|||
Standardized measure, end of period(a)
|
|
$
|
9,000
|
|
|
$
|
9,495
|
|
|
$
|
7,490
|
|
(a)
|
The impact of cash flow hedges has not been included in any of the periods presented.
|
(b)
|
Excludes gains and losses on derivatives.
|
ITEM 9.
|
Changes In and Disagreements with Accountants on Accounting and Financial Disclosure
|
ITEM 9A.
|
Controls and Procedures
|
ITEM 9B.
|
Other Information
|
ITEM 10.
|
Directors, Executive Officers and Corporate Governance
|
ITEM 11.
|
Executive Compensation
|
ITEM 12.
|
Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
|
ITEM 13.
|
Certain Relationships and Related Transactions and Director Independence
|
ITEM 14.
|
Principal Accountant Fees and Services
|
ITEM 15.
|
Exhibits and Financial Statement Schedules
|
(a)
|
The following financial statements, financial statement schedules and exhibits are filed as a part of this report:
|
1.
|
Financial Statements. Chesapeake's consolidated financial statements are included in Item 8 of Part II of this report. Reference is made to the accompanying Index to Financial Statements.
|
2.
|
Financial Statement Schedules. No financial statement schedules are applicable or required.
|
3.
|
Exhibits. The exhibits listed below in the Index of Exhibits are filed, furnished or incorporated by reference pursuant to the requirements of Item 601 of Regulation S-K.
|
|
|
|
|
Incorporated by Reference
|
|
|
||||||
Exhibit
Number
|
|
Exhibit Description
|
|
Form
|
|
SEC File
Number
|
|
Exhibit
|
|
Filing Date
|
|
Filed or
Furnished
Herewith
|
2.1
|
|
|
10-Q
|
|
001-13726
|
|
2.1
|
|
10/30/2018
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2.2.1*
|
|
|
8-K
|
|
001-13726
|
|
2.1
|
|
10/30/2018
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2.2.2
|
|
|
S-4/A
|
|
333-228679
|
|
Annex A
|
|
12/19/2018
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3.1.1
|
|
|
10-K
|
|
001-13726
|
|
3.1.1
|
|
2/27/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3.1.2
|
|
|
10-Q
|
|
001-13726
|
|
3.1.4
|
|
11/10/2008
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3.1.3
|
|
|
10-Q
|
|
001-13726
|
|
3.1.6
|
|
8/11/2008
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3.1.4
|
|
|
8-K
|
|
001-13726
|
|
3.2
|
|
5/20/2010
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3.1.5
|
|
|
10-Q
|
|
001-13726
|
|
3.1.5
|
|
8/9/2010
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3.2
|
|
|
8-K
|
|
001-13726
|
|
3.2
|
|
6/19/2014
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.1**
|
|
|
8-K
|
|
001-13726
|
|
4.1.1
|
|
11/15/2005
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.2.1**
|
|
|
S-3
|
|
333-168509
|
|
4.1
|
|
8/3/2010
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.2.2
|
|
|
8-A
|
|
001-13726
|
|
4.3
|
|
9/24/2010
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.2.3
|
|
|
8-A
|
|
001-13726
|
|
4.2
|
|
2/22/2011
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.2.4
|
|
|
S-3
|
|
333-168509
|
|
4.17
|
|
3/18/2013
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.2.5
|
|
|
8-A
|
|
001-13726
|
|
4.3
|
|
4/8/2013
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.2.6
|
|
|
8-A
|
|
001-13726
|
|
4.4
|
|
4/8/2013
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.3.1**
|
|
|
8-K
|
|
001-13726
|
|
4.1
|
|
4/29/2014
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.3.2
|
|
|
8-K
|
|
001-13726
|
|
4.3
|
|
4/29/2014
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.4.1
|
|
|
8-K
|
|
001-13726
|
|
10.1
|
|
9/12/2018
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.4.2
|
|
|
8-K
|
|
001-13726
|
|
10.1
|
|
2/1/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.4.3
|
|
|
8-K
|
|
001-13726
|
|
10.1
|
|
12/4/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.4.4
|
|
|
8-K
|
|
001-13726
|
|
10.1
|
|
12/27/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.5
|
|
|
8-K
|
|
001-13726
|
|
10.1
|
|
12/23/2015
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.6
|
|
|
8-K
|
|
001-13726
|
|
10.2
|
|
12/23/2015
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.7
|
|
|
8-K
|
|
001-13726
|
|
4.1
|
|
10/5/2016
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.8
|
|
|
8-K
|
|
001-13726
|
|
4.2
|
|
12/20/2016
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.9
|
|
|
8-K
|
|
001-13726
|
|
4.2
|
|
6/7/2017
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.10
|
|
|
8-K
|
|
001-13726
|
|
4.2
|
|
9/27/2018
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.11
|
|
|
8-K
|
|
001-13726
|
|
4.3
|
|
9/27/2018
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.12
|
|
|
8-K
|
|
001-13726
|
|
4.2
|
|
4/5/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.13
|
|
|
8-K
|
|
001-13726
|
|
4.4
|
|
4/5/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.14.1
|
|
|
8-K
|
|
001-37964
|
|
4.1
|
|
2/1/2017
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.14.2
|
|
|
10-Q
|
|
001-37964
|
|
4.6
|
|
8/10/2017
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.14.3
|
|
|
10-K
|
|
001-37964
|
|
4.6
|
|
3/12/2018
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.14.4
|
|
|
10-Q
|
|
001-37964
|
|
4.6
|
|
8/9/2018
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.14.5
|
|
|
8-K
|
|
001-13726
|
|
4.1
|
|
2/1/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.14.6
|
|
|
8-K
|
|
001-13726
|
|
4.5
|
|
12/26/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.15.1
|
|
|
8-K
|
|
001-13726
|
|
4.1
|
|
12/26/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.15.2
|
|
|
8-K
|
|
001-13726
|
|
4.2
|
|
12/26/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.16
|
|
|
8-K
|
|
001-13726
|
|
4.3
|
|
12/26/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.17
|
|
|
8-K
|
|
001-13726
|
|
4.4
|
|
12/26/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4.18
|
|
|
|
|
|
|
|
|
|
|
X
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.1.1†
|
|
|
8-K
|
|
001-13726
|
|
10.1
|
|
6/20/2013
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.1.2†
|
|
|
8-K
|
|
001-13726
|
|
10.1
|
|
2/4/2013
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.2.1†
|
|
|
10-K
|
|
001-13726
|
|
10.3
|
|
2/25/2016
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.2.2†
|
|
|
10-K
|
|
001-13726
|
|
10.3.2
|
|
2/27/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.3.1†
|
|
|
10-K
|
|
001-13726
|
|
10.16
|
|
3/1/2013
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.3.2†
|
|
|
10-K
|
|
001-13726
|
|
10.3.2
|
|
3/3/2017
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.4.1†
|
|
|
8-K
|
|
001-13726
|
|
10.1
|
|
5/23/2013
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.4.2†
|
|
|
8-K
|
|
001-13726
|
|
10.1
|
|
6/17/2016
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.4.3†
|
|
|
8-K
|
|
001-13726
|
|
10.1
|
|
1/4/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.4.4†
|
|
|
10-Q
|
|
001-13726
|
|
10.1
|
|
8/1/2018
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.5†
|
|
|
8-K
|
|
001-13726
|
|
10.2
|
|
1/4/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.6†
|
|
|
8-K
|
|
001-13726
|
|
10.3
|
|
1/4/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.7†
|
|
|
8-K
|
|
001-13726
|
|
10.4
|
|
1/4/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.8†
|
|
|
10-K
|
|
001-13726
|
|
10.10
|
|
2/27/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.9†
|
|
|
10-K
|
|
001-13726
|
|
10.11
|
|
2/27/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.10†
|
|
|
8-K
|
|
001-13726
|
|
10.3
|
|
6/27/2012
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.11†
|
|
|
DEF 14A
|
|
001-13726
|
|
Exhibit G
|
|
5/3/2013
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.12.1†
|
|
|
10-Q
|
|
001-13726
|
|
10.1
|
|
8/3/2017
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.12.2†
|
|
|
10-Q
|
|
001-13726
|
|
10.2
|
|
8/6/2014
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.12.3†
|
|
|
10-Q
|
|
001-13726
|
|
10.3
|
|
8/6/2014
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.12.4†
|
|
|
10-Q
|
|
001-13726
|
|
10.4
|
|
8/6/2014
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.12.5†
|
|
|
10-Q
|
|
001-13726
|
|
10.10
|
|
5/9/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.12.6†
|
|
|
10-Q
|
|
001-13726
|
|
10.6
|
|
8/6/2014
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.13
|
|
|
8-K
|
|
001-13726
|
|
10.3
|
|
10/30/2018
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.14
|
|
|
8-K
|
|
001-13726
|
|
10.1
|
|
12/26/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.15
|
|
|
8-K
|
|
001-13726
|
|
10.2
|
|
12/26/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10.16
|
|
|
8-K
|
|
001-13726
|
|
10.3
|
|
12/26/2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
21
|
|
|
|
|
|
|
|
|
|
|
X
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
23.1
|
|
|
|
|
|
|
|
|
|
|
X
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
23.2
|
|
|
|
|
|
|
|
|
|
|
X
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
31.1
|
|
|
|
|
|
|
|
|
|
|
X
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
31.2
|
|
|
|
|
|
|
|
|
|
|
X
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
32.1
|
|
|
|
|
|
|
|
|
|
|
X
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
32.2
|
|
|
|
|
|
|
|
|
|
|
X
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
95.1
|
|
|
|
|
|
|
|
|
|
|
X
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ITEM 16.
|
Form 10-K Summary
|
|
CHESAPEAKE ENERGY CORPORATION
|
||
|
|
|
|
Date: February 27, 2020
|
By:
|
|
/s/ ROBERT D. LAWLER
|
|
|
|
Robert D. Lawler
|
|
|
|
President and Chief Executive Officer
|
Signature
|
|
Capacity
|
|
Date
|
/s/ ROBERT D. LAWLER
|
|
President and Chief Executive Officer
(Principal Executive Officer)
|
|
February 27, 2020
|
Robert D. Lawler
|
||||
|
|
|
|
|
/s/ DOMENIC J. DELL'OSSO, JR.
|
|
Executive Vice President
and Chief Financial Officer
(Principal Financial Officer)
|
|
February 27, 2020
|
Domenic J. Dell'Osso, Jr.
|
||||
|
|
|
|
|
/s/ WILLIAM M. BUERGLER
|
|
Senior Vice President
and Chief Accounting Officer
(Principal Accounting Officer)
|
|
February 27, 2020
|
William M. Buergler
|
||||
|
|
|
|
|
/s/ R. BRAD MARTIN
|
|
Chairman of the Board
|
|
February 27, 2020
|
R. Brad Martin
|
||||
|
|
|
|
|
/s/ GLORIA R. BOYLAND
|
|
Director
|
|
February 27, 2020
|
Gloria R. Boyland
|
||||
|
|
|
|
|
/s/ LUKE R. CORBETT
|
|
Director
|
|
February 27, 2020
|
Luke R. Corbett
|
||||
|
|
|
|
|
/s/ MARK A. EDMUNDS
|
|
Director
|
|
February 27, 2020
|
Mark A. Edmunds
|
||||
|
|
|
|
|
/s/ LESLIE S. KEATING
|
|
Director
|
|
February 27, 2020
|
Leslie S. Keating
|
||||
|
|
|
|
|
/s/ MERRILL A. MILLER, JR.
|
|
Director
|
|
February 27, 2020
|
Merrill A. Miller, Jr.
|
||||
|
|
|
|
|
/s/ THOMAS L. RYAN
|
|
Director
|
|
February 27, 2020
|
Thomas L. Ryan
|
•
|
14,436,542 shares that were unissued and undesignated as to series; and
|
•
|
5,563,458 shares that were issued and designated as 4.5% preferred stock, 5.00% Cumulative Convertible Preferred Stock (Series 2005B), 5.75% Cumulative Convertible Non-Voting Preferred Stock (Series A) and 5.75% Cumulative Non-Voting Convertible Preferred Stock.
|
•
|
in cash;
|
•
|
by delivery of shares of our Common stock; or
|
•
|
through any combination of cash and our Common stock.
|
•
|
the Mandatory Conversion Date;
|
•
|
the number of shares of common stock to be issued upon conversion of each share of 4.5% preferred stock
|
•
|
the number of shares of 4.5% preferred stock to be converted; and
|
•
|
that dividends on the 4.5% preferred stock to be converted will cease to accrue on the Mandatory Conversion Date.
|
•
|
any payment of a dividend (or other distribution) payable in shares of common stock on any class of our capital stock other than the 4.5% preferred stock;
|
•
|
any issuance to all holders of shares of common stock of rights, options or warrants entitling them to subscribe for or purchase shares of common stock or securities convertible into or exchangeable for shares of common stock at less than the Market Value for the period ending on the date of issuance; provided, however, that no adjustment shall be made with respect to such a distribution if the holder of shares of 4.5% preferred stock would be entitled to receive such rights, options or warrants upon conversion at any time of shares of 4.5% preferred stock into common stock; provided further, however, that if such rights, options or warrants are only exercisable upon the occurrence of certain triggering events, then the Conversion Price will not be adjusted until such triggering events occur;
|
•
|
any subdivision, combination or reclassification of the common stock;
|
•
|
any dividend or distribution to all holders of shares of common stock (other than a dividend or distribution referred to in the second bullet point above) made pursuant to any shareholder rights plan, “poison pill” or similar arrangement and excluding dividends payable upon the 4.5% preferred stock;
|
•
|
any distribution by us consisting exclusively of cash to all holders of our common stock, excluding any cash dividend on our common stock to the extent that the aggregate cash dividend per share of our common stock in any quarterly period does not exceed $0.065 (the “dividend threshold amount”); the dividend threshold amount is subject to adjustment under the same circumstances under which the Conversion Price is subject to adjustment; provided, however, that no adjustment will be made to the dividend threshold amount for any adjustment made to the Conversion Price pursuant to this clause, in which event the Conversion Price will be adjusted by multiplying:
|
(1)
|
the Conversion Price by
|
(2)
|
a fraction, the numerator of which will be the Market Value of a share of our common stock minus the amount per share of such dividend increase (as determined below) or distribution and the denominator of which will be the Market Value of a share of our common stock.
|
•
|
the completion of a tender or exchange offer made by us or any of our subsidiaries for shares of common stock that involves an aggregate consideration that, together with (a) any cash and other consideration payable in a tender or exchange offer by us or any of our subsidiaries for shares of common stock expiring within the then-preceding 12 months in respect of which no adjustment has been made and (b) the aggregate amount of any such all-cash distributions referred to in the preceding bullet point to all holders of shares of common stock within the then-preceding 12 months in respect of which no adjustments have been made, exceeds 15% of our market capitalization on the expiration of such tender offer; or
|
•
|
a distribution to all holders of common stock consisting of evidences of indebtedness, shares of capital stock other than common stock or assets (including securities, but excluding those dividends, rights, options, warrants and distributions referred to above).
|
•
|
if such conversion occurs on or prior to the date for the distribution to the holders of rights or warrants of separate certificates evidencing such rights or warrants (which we will refer to as the “Distribution Date”), the same number of rights or warrants to which a holder of a number of shares of common stock equal to the number of Conversion Shares is entitled at the time of such conversion in accordance with the terms and provisions applicable to the rights or warrants; and
|
•
|
if such conversion occurs after such Distribution Date, the same number of rights or warrants to which a holder of the number of shares of common stock into which such 4.5% preferred stock was convertible immediately prior to such Distribution Date would have been entitled on such Distribution Date had such 4.5% preferred stock been converted immediately prior to such Distribution Date in accordance with the terms and provisions applicable to the rights or warrants.
|
•
|
common stock and cash in lieu of fractional shares, as described under “—Conversion Rights” (subject to adjustment as described above under “—Conversion Price Adjustment”) and “—Fractional Shares”; and
|
•
|
the make-whole premium, if any.
|
•
|
the sale, lease or transfer, in one or a series of related transactions, of all or substantially all of our assets (determined on a consolidated basis) to any person or group (as such term is used in Section 13(d)(3) of the Exchange Act), other than to Permitted Holders (as defined in the certificate of designation);
|
•
|
the adoption of a plan the consummation of which would result in our liquidation or dissolution;
|
•
|
the acquisition, directly or indirectly, by any person or group (as such term is used in Section 13(d)(3) of the Exchange Act) other than Permitted Holders, of beneficial ownership (as defined in Rule 13d-3 under the Exchange Act) of more than 50% of the aggregate voting power of our voting stock; provided, however, that the Permitted Holders beneficially own (as defined in Rules 13d-3 and 13d-5 under the Exchange Act), directly or indirectly, in the aggregate a lesser percentage of the total voting power of our voting stock than such other person or group and do not have the right or ability by voting power, contract or otherwise to elect or designate for election a majority of our board of directors (for the purposes of this definition, such other person or group shall be deemed to beneficially own any voting stock of a specified corporation held by a parent corporation, if such other person or group is the beneficial owner (as defined above), directly or indirectly, of more than 35% of the voting power of the voting stock of such parent corporation and the Permitted Holders beneficially own (as defined in this proviso), directly or indirectly, in the aggregate a lesser percentage of the voting power of the voting stock of such parent corporation and do not have the right or ability by voting power, contract or otherwise to elect or designate for election a majority of the board of directors of such parent corporation);
|
•
|
during any period of two consecutive years, individuals who at the beginning of such period comprised our board of directors (together with any new directors whose election by such board of directors or whose nomination for election by our shareholders was approved by a vote of 66 2/3% of our directors
|
•
|
our common stock ceases to be listed on a national securities exchange or quoted on Nasdaq or another over-the-counter market in the United States.
|
•
|
equal to a percentage of the liquidation preference of the 4.5% preferred stock converted determined by reference to the table below, based on the Effective Date and the price (the “Stock Price”) paid, or deemed to be paid, per share of our common stock in the transaction constituting the Fundamental Change, subject to adjustment as described below; and
|
•
|
in addition to, and not in substitution for, any cash, securities or other assets otherwise due to holders of 4.5% preferred stock upon conversion.
|
(1)
|
In the case of a Fundamental Change in which all or substantially all of the shares of our common stock have been, as of the Effective Date, converted into or exchanged for the right to receive securities or other assets or property, the consideration shall be valued as follows:
|
(a)
|
securities that are traded on a U.S. national securities exchange or approved for quotation on the Nasdaq or any similar system of automated dissemination of quotations of
|
(b)
|
other securities, assets or property, other than cash, that holders will have the right to receive will be valued based on the average of the fair market value of the securities, assets or property, other than cash, as determined by two independent nationally recognized investment banks, and
|
(c)
|
100% of any cash.
|
(2)
|
In all other cases, the value of our common stock will equal the average of the closing prices of our common stock for the five consecutive Trading Days beginning on the second Trading Day after the Fundamental Change Notice Date.
|
•
|
before the person became an interested shareholder, the board of directors of the corporation approved the business combination or transaction in which the person became an interested shareholder;
|
•
|
upon consummation of the transaction that resulted in the person becoming an interested shareholder, the interested shareholder owned stock having at least 85% of all voting power of the corporation when the transaction commenced, excluding for purposes of determining the outstanding voting stock, but not the outstanding voting stock owned by the interested shareholder, stock held by directors who are also officers of the corporation and stock held by certain employee stock plans; or
|
•
|
after the person became an interested shareholder, the business combination is approved by the board of directors of the corporation and authorized at a meeting of shareholders, and not by written consent, by the affirmative vote of the holders of at least two-thirds of all voting power not attributable to shares owned by the interested shareholder.
|
•
|
any merger or consolidation involving the corporation and an interested shareholder;
|
•
|
any sale, lease, exchange, mortgage, pledge, transfer or other disposition to or with an interested shareholder of 10% or more of the assets of the corporation;
|
•
|
subject to certain exceptions, any transaction which results in the issuance or transfer by the corporation of any stock of the corporation to an interested shareholder;
|
•
|
any transaction involving the corporation which has the effect of increasing the proportionate share of the stock of any class or series or voting power of the corporation owned by the interested shareholder;
|
•
|
the receipt by an interested shareholder of the benefit of any loans, advances, guarantees, pledges or other financial benefits provided by or through the corporation; or
|
•
|
any share acquisition by the interested shareholder pursuant to Section 1090.1 of the OGCA.
|
(1)
|
the Company or such subsidiary would be entitled to incur Funded Debt or Indebtedness, as the case may be, secured by Liens in a principal amount equal to the Attributable Indebtedness (under the 2010 and 2014 Indentures, treated as if such Attributable Indebtedness were Funded Debt) with respect to such Sale/Leaseback Transaction; provided, however, that, under the 2010 and 2014 Indentures, Attributable Indebtedness in respect of any Sale/Leaseback Transaction entered into pursuant to this clause will not count against the amount of Funded Debt or permitted under the Secured Debt Basket for any other purpose, including when determining the amount available thereunder for future Sale/Leaseback Transactions or any Funded Debt transactions; or
|
(2)
|
the Company or such Restricted Subsidiary receives proceeds from such Sale/Leaseback Transaction at least equal to the fair market value thereof (as determined in good faith by the Company) and such proceeds are applied in accordance with the following two paragraphs.
|
(1)
|
the repayment of Indebtedness of the Company or a Restricted Subsidiary under Credit Facilities or other Senior Indebtedness, including any redemption or repurchase of existing notes or the Notes;
|
(2)
|
make an Investment in assets used or useful in the Oil and Gas Business (including Capital Stock of Persons engaged in the Oil and Gas Business); or
|
(3)
|
develop by drilling the Company’s oil and gas reserves.
|
1.
|
default by the Company or any subsidiary guarantor in the payment of principal of or any premium on such Notes when due and payable at Maturity and, in the case of Notes issued under the 2005 Indenture, upon a failure to repurchase pursuant to such Indenture, upon acceleration or otherwise;
|
2.
|
default by the Company or any subsidiary guarantor in the payment of any installment of interest on such Notes when due and payable and continuance of such default for 30 days;
|
3.
|
default by the Company or any subsidiary guarantor with respect to any other Indebtedness of the Company or any subsidiary guarantor if either
|
a.
|
such default results in the acceleration of the maturity of certain indebtedness having a principal amount of $50.0 million or more under the 2005 Indenture or $75.0 million or more under the 2010 and 2014 Indentures, individually or, taken together with the principal amount of any other such Indebtedness the maturity of which has been so accelerated, in the aggregate, or
|
b.
|
such default results from the failure to pay when due principal of any such Indebtedness, after giving effect to any applicable grace period (a “Payment Default”), having a principal amount of $50.0 million or more under the 2005 Indenture or $75.0 million or more under the 2010 and 2014 Indentures individually or, taken together with the principal amount of any other Indebtedness under which there has been a Payment Default, in the aggregate;
|
4.
|
default in the performance, or breach of, any covenant or agreement of the Company or any subsidiary guarantor in the applicable Indenture governing such Notes and, in each such case, failure to remedy such default within a period of 60 days after written notice thereof from the applicable trustee or holders of 25% of the principal amount of the applicable Notes; provided, however, that under the 2010 and 2014 Indentures, the Company will have 90 days following such written notice to remedy or receive a waiver for any failure to comply with its obligations under such Indenture so long as the Company is attempting to remedy any such failure as promptly as reasonably practicable;
|
5.
|
the failure of a Guarantee by a subsidiary guarantor to be in full force and effect, or the denial or disaffirmance by such entity thereof; or
|
6.
|
certain events involving bankruptcy, insolvency or reorganization of the Company or any subsidiary guarantor.
|
1.
|
default by the Company or any subsidiary guarantor in the deposit of any make-whole redemption payment when and as due and payable; and
|
2.
|
the entry by a court of one or more judgments or orders for the payment of money against the Company, any subsidiary guarantor or other subsidiary in an aggregate amount in excess of $50.0 million that has not been vacated, discharged, satisfied or stayed pending appeal within 60 days from the entry thereof.
|
(1)
|
the applicable trustee has received written notice of a continuing Event of Default,
|
(2)
|
the applicable trustee has received a request from holders of at least 25% in principal amount of such Notes to pursue such remedy,
|
(3)
|
the applicable trustee has been offered indemnity reasonably satisfactory to it,
|
(4)
|
the applicable trustee has failed to act for a period of 60 days after receipt of such notice, request and offer of indemnity, and
|
(5)
|
no direction inconsistent with such written request has been given to the applicable trustee during such 60-day period by the holders of a majority in principal amount of such Notes;
|
(1)
|
the rights of holders of such outstanding Notes to receive payments solely from the trust fund described in the applicable Indenture in respect of the principal of, and any premium and interest on, such Notes when such payments are due;
|
(2)
|
the Company’s obligations with respect to such Notes concerning the issuance of temporary notes, transfers and exchanges of such Notes, replacement of mutilated, destroyed, lost or stolen Notes, the maintenance of an office or agency where such Notes may be surrendered for transfer or exchange or presented for payment, and duties of paying agents;
|
(3)
|
the rights, powers, trusts, duties and immunities of the applicable trustee, and the Company’s obligations in connection therewith; and
|
(4)
|
the Defeasance provisions of such Indenture.
|
(1)
|
the Company must irrevocably deposit with the applicable trustee, in trust, for the benefit of the holders of such Notes, cash in U.S. Legal Tender, U.S. Government Securities, or a combination thereof, in such amounts as will be sufficient, in the opinion of a nationally recognized firm of independent public accountants, to pay the principal of, and any premium, if any, and interest on, such outstanding Notes on each date on which such principal and any premium and interest is due and payable under such Indenture or on any redemption date established pursuant to such Indenture (provided that, upon any redemption that requires the payment of a Make-Whole Premium, (x) the amount of cash, U.S. Government Securities, or combination thereof, that must be deposited will be determined using an assumed applicable premium calculated as of the date of such deposit and (y) the Company will deposit any deficit in trust on or prior to the redemption date as necessary to pay the applicable premium as determined by such date);
|
(2)
|
in the case of Legal Defeasance, the Company must deliver to the trustee an opinion of counsel reasonably acceptable to the trustee confirming that (i) the Company has received from or there has been published by the Internal Revenue Service a ruling or (ii) since the date of the applicable Indenture, there has been a change in the applicable federal income tax law, in either case to the effect that , and based thereon such opinion of counsel shall confirm that, the holders of such outstanding Notes will not recognize income, gain or loss for U.S. Federal income tax purposes as a result of such Legal Defeasance and will be subject to U.S. Federal income tax on the same amounts, in the same manner and at the same times as would have been the case if such Legal Defeasance had not occurred;
|
(3)
|
in the case of Covenant Defeasance, the Company must deliver to the applicable trustee an opinion of counsel reasonably acceptable to the trustee to the effect that the holders of such outstanding Notes will not recognize income, gain or loss for U.S. Federal income tax purposes as a result of such Covenant Defeasance and will be subject to federal income tax on the same amounts, in the same manner and at the same times as would have been the case if such Covenant Defeasance had not occurred;
|
(4)
|
the Company must deliver to the applicable trustee an officers’ certificate stating that the deposit was not made by the Company with the intent of preferring the holders of such Notes over other creditors of the Company or with the intent of defeating, hindering, delaying or defrauding creditors of the Company or others;
|
(5)
|
the Company must deliver to the applicable trustee an officers’ certificate and an opinion of counsel each stating that the Company has complied with all conditions precedent to the Legal Defeasance or the Covenant Defeasance, as the case may be;
|
(6)
|
no Default or Event of Default has occurred and is continuing on the date of such deposit or insofar as Events of Default from bankruptcy or insolvency events are concerned, at any time in the period ending on the 91st day after the date of deposit;
|
(7)
|
such Legal Defeasance or Covenant Defeasance does not result in a breach or violation of, or constitute a default under, any other material agreement, other than the applicable Indenture, or instrument to which the Company is a party or by which the Company is bound.
|
(1)
|
delivers all such outstanding Notes to the applicable trustee for cancellation; or
|
(2)
|
all such Notes not so delivered for cancellation have either become due and payable or will become due and payable at their maturity within one year or are called for redemption within one year, and in the case of this Section (2) the Company has deposited with the trustee in trust an amount of cash sufficient to pay the entire indebtedness of such Notes, including any premium and interest to the Maturity Date or applicable redemption date (provided that, upon any redemption that requires the payment of a Make-Whole Premium, (x) the amount of cash that must be deposited will be determined using an assumed applicable premium calculated as of the date of such deposit and (y) the Company will deposit any deficit in trust on or prior to the redemption date as necessary to pay the applicable premium as determined by such date).
|
(1)
|
reduce the percentage of principal amount of such Notes whose holders must consent to an amendment, supplement or waiver of any provision of the applicable Indenture or such Notes;
|
(2)
|
reduce the rate or change the time for payment of interest, including default interest, if any, on such Notes of any series;
|
(3)
|
reduce the principal amount of any such Note or change the Maturity Date of such Notes;
|
(4)
|
reduce the amount payable upon redemption of any such Note;
|
(5)
|
adversely affect the conversion rights of any such Note that is convertible in accordance with the applicable provisions of such Note;
|
(6)
|
waive any Event of Default in the payment of principal of, any premium or interest on such Notes;
|
(7)
|
make any such Note payable in money other than that stated in such Note;
|
(8)
|
impair the right of holders of such Notes to receive payment of the principal of and interest on the Notes on the respective due dates therefor and to institute suit for the enforcement of any such payment; or
|
(9)
|
make any change in the percentage of principal amount of such Notes necessary to waive compliance with certain provisions of the applicable Indenture.
|
(1)
|
to cure any ambiguity, omission, defect or inconsistency;
|
(2)
|
to comply with certain provisions of such Indenture;
|
(3)
|
to add to, change or eliminate any of the provisions of such Indenture; provided that any such addition, change or elimination will not be effective as to Notes issued thereunder and outstanding prior to the date of such amendment or supplement;
|
(4)
|
to establish the forms or terms of the Notes of any series issued under such Indenture;
|
(5)
|
to evidence the acceptance or appointment of a separate trustee or successor trustee;
|
(6)
|
in the case of any Notes issued under the 2010 or 2014 Indenture that are designated as Subordinated Debt Securities under such Indenture, to make any change in Article Eleven of such Indenture that would limit or terminate the benefits available to any holder of Senior Indebtedness under such Article Eleven;
|
(7)
|
to reflect the addition or release of any subsidiary guarantor, as provided for by such Indenture, or to secure any of the Notes issued thereunder or the applicable Guarantees;
|
(8)
|
to comply with any requirements of the SEC in order to effect or maintain the qualification of the applicable Indenture under the Trust Indenture Act;
|
(9)
|
to provide for uncertificated Notes in addition to certificated Notes;
|
(10)
|
to make provisions with respect to the conversion of Notes of any series that are convertible in accordance with the terms of such Notes; or
|
(11)
|
to make any change that would provide any additional benefit or rights to the holders of such series or that does not adversely affect the rights of any holder of such series in any material respect.
|
(1)
|
discounted future net revenue from proved oil and gas reserves of the Company and its Subsidiaries calculated in accordance with SEC guidelines before any state or federal income taxes, as estimated by petroleum engineers (which may include the Company’s internal engineers) in a reserve report prepared as of the end of the Company’s most recently completed fiscal year, as increased by, as of the date of determination, the discounted future net revenue of (A) estimated proved oil and gas reserves of the Company and its Subsidiaries attributable to any acquisition consummated since the date of such year-end reserve report and (B) estimated proved oil and gas reserves of the Company and its Subsidiaries attributable to extensions, discoveries and other additions and upward revisions of estimates of proved oil and gas reserves due to exploration, development or exploitation, production or other activities conducted or otherwise occurring since the date of such year-end reserve report which, in the case of sub-clauses (A) and (B), would, in accordance with standard industry practice, result in such increases as calculated in accordance with SEC guidelines (utilizing the prices utilized in such year-end reserve report), and decreased by, as of the date of determination, the discounted future net revenue of (C) estimated proved oil and gas reserves of the Company and its Subsidiaries produced or disposed of since the date of such year-end reserve report and (D) reductions in the estimated oil and gas reserves of the Company and its Subsidiaries since the date of such year-end reserve report attributable to downward revisions of estimates of proved oil and gas reserves due to exploration, development or exploitation, production or other activities conducted or otherwise occurring since the date of such year-end reserve report which, in the case of sub-clauses (C) and (D) would, in accordance with standard industry practice, result in such decreases as calculated in accordance with SEC
|
(2)
|
the capitalized costs that are attributable to oil and gas properties of the Company and its Subsidiaries to which no proved oil and gas reserves are attributable, based on the Company’s books and records as of a date no earlier than the date of the Company’s latest annual or quarterly financial statements,
|
(3)
|
the Net Working Capital on a date no earlier than the date of the Company’s latest annual or quarterly financial statements, and
|
(4)
|
the greater of (A) the net book value on a date no earlier than the date of the Company’s latest annual or quarterly financial statements and (B) the appraised value, as estimated by independent appraisers, of other tangible assets (including Investments in unconsolidated Subsidiaries) of the Company and its Subsidiaries, as of a date no earlier than the date of the Company’s latest audited financial statements, minus (b) the sum of
|
a.
|
minority interests,
|
b.
|
any gas balancing liabilities of the Company and its Subsidiaries reflected as a long-term liability in the Company’s latest annual or quarterly financial statement,
|
c.
|
the discounted future net revenue, calculated in accordance with SEC guidelines (utilizing the prices utilized in the Company’s year-end reserve report), attributable to reserves which are required to be delivered to third parties to fully satisfy the obligations of the Company and its Subsidiaries with respect to Volumetric Production Payments on the schedules specified with respect thereto,
|
d.
|
the discounted future net revenue, calculated in accordance with SEC guidelines, attributable to reserves subject to Dollar-Denominated Production Payments which, based on the estimates of production included in determining the discounted future net revenue specified in (a)(1) above (utilizing the same prices utilized in the Company’s year-end reserve report), would be necessary to fully satisfy the payment obligations of the Company and its Subsidiaries with respect to Dollar-Denominated Production Payments on the schedules specified with respect thereto, and
|
e.
|
the discounted future net revenue, calculated in accordance with SEC guidelines (utilizing the same prices utilized in the Company’s year-end or quarterly reserve report, as applicable), attributable to reserves subject to participation interests, overriding royalty interests or other interests of third parties, pursuant to participation, partnership, vendor financing or other agreements then in effect, or which otherwise are required to be delivered to third parties.
|
(i)
|
with respect to a series of Notes, Liens existing on the issue date of such series of Notes;
|
(ii)
|
Liens securing certain indebtedness under Credit Facilities;
|
(iii)
|
Liens securing any renewal, extension, substitution, refinancing or replacement of secured certain indebtedness; provided, that such Liens extend to or cover only the property or assets then securing the certain indebtedness being refinanced and that the certain indebtedness being refinanced was not incurred under the Credit Facilities;
|
(iv)
|
Liens on, or related to, properties to secure all or part of the costs incurred in the ordinary course of business of exploration, drilling, development or operation thereof;
|
(v)
|
Liens upon (a) any property of or any interests in any Person existing at the time of acquisition of such property or interests by the Company or a Subsidiary, (b) any property of or interests in a Person existing at the time such Person is merged or consolidated with the Company or any Subsidiary or existing at the time of the sale or transfer of any such property of or interests in such Person to the Company or any Subsidiary, or (c) any property of or interests in a Person existing at the time such Person becomes a Subsidiary; provided, that in each case such Lien has not been created in contemplation of such sale, merger, consolidation, transfer or acquisition, and provided, further, that in each such case no such Lien will extend to or cover any property of the Company or any Subsidiary other than the property being acquired and improvements thereon;
|
(vi)
|
Liens on deposits to secure public or statutory obligations or in lieu of surety or appeal bonds entered into in the ordinary course of business;
|
(vii)
|
Liens in favor of collecting or payor banks having a right of setoff, revocation, refund or chargeback with respect to money or instruments of the Company or any Subsidiary on deposit with or in possession of such bank;
|
(viii)
|
purchase money security interests granted in connection with the acquisition of assets in the ordinary course of business and consistent with past practices, provided, that (a) such Liens attach only to the property so acquired with the purchase money indebtedness secured thereby and (b) such Liens secure only certain indebtedness that is not in excess of 100% of the purchase price of such assets;
|
(ix)
|
Liens reserved in oil and gas mineral leases for bonus or rental payments and for compliance with the terms of such leases;
|
(x)
|
Liens arising under partnership agreements, oil and gas leases, farm-out agreements, division orders, contracts for the sale, purchase, exchange, transportation or processing of oil, gas or other hydrocarbons, unitization and pooling declarations and agreements, development agreements, operating agreements, area of mutual interest agreements, and other similar agreements which are customary in the Oil and Gas Business;
|
(xi)
|
Liens securing obligations of the Company or any of its Subsidiaries under Oil and Gas Hedging Contracts;
|
(xii)
|
Liens in favor of the United States, any State thereof, any foreign country or any department, agency or instrumentality or political subdivision of any such jurisdiction, to secure partial, progress, advance or other payments pursuant to any contract or statute or to secure any indebtedness incurred for the purpose of financing all or any part of the purchase price or the cost of constructing or improving the property subject to such Liens, including without limitation, Liens to secure Funded Debt of the pollution control or industrial revenue bond type; and
|
(xiii)
|
Liens in favor of the Company or any subsidiary guarantor.
|
(i)
|
property or assets employed in gathering, treating, processing, refining, transportation, distribution or marketing,
|
(ii)
|
accounts receivable and other obligations of any obligor under a contract for the sale, exploration, production, drilling, development, processing or transportation of crude oil, condensate, natural gas, natural gas liquids or other similar hydrocarbon substances by the Company or any of its Subsidiaries, and all related rights of the Company or any of its Subsidiaries, and all guarantees, insurance, letters of credit and other agreements or arrangements of whatever character supporting or securing payment of such receivables or obligations, or
|
(iii)
|
the production or any proceeds from production of crude oil, condensate, natural gas, natural gas liquids or other similar hydrocarbon substances.
|
(a)
|
all obligations of such Person
|
(i)
|
in respect of borrowed money (whether or not the recourse of the lender is to the whole of the assets of such Person or only to a portion thereof),
|
(ii)
|
evidenced by bonds, notes, debentures or similar instruments,
|
(iii)
|
representing the balance deferred and unpaid of the purchase price of any property or services (other than accounts payable or other obligations arising in the ordinary course of business),
|
(iv)
|
evidenced by bankers’ acceptances or similar instruments issued or accepted by banks,
|
(v)
|
for the payment of money relating to a Capitalized Lease Obligation, or
|
(vi)
|
evidenced by a letter of credit or a reimbursement obligation of such Person with respect to any letter of credit;
|
(b)
|
all net obligations of such Person under Interest Rate Hedging Agreements, Oil and Gas Hedging Contracts and Currency Hedge Obligations, except to the extent such net obligations are taken into account in the determination of future net revenues from proved oil and gas reserves for purposes of the calculation of Adjusted Consolidated Net Tangible Assets;
|
(c)
|
all liabilities of others of the kind described in the preceding clauses (a) or (b) that such Person has guaranteed or that are otherwise its legal liability (including, with respect to any Production Payment, any warranties or guaranties of production or payment by such Person with respect to such Production Payment but excluding other contractual obligations of such Person with respect to such Production Payment);
|
(d)
|
Indebtedness (as otherwise defined in this definition) of another Person secured by a Lien on any asset of such Person, whether or not such Indebtedness is assumed by such Person, the amount of such obligations being deemed to be the lesser of (1) the full amount of such obligations so secured, and (2) the fair market value of such asset, as determined in good faith by the board of directors of such Person, which determination shall be evidenced by a Board Resolution,
|
(e)
|
with respect to such Person, the liquidation preference or any mandatory redemption payment obligations in respect of Disqualified Stock;
|
(f)
|
the aggregate preference in respect of amounts payable on the issued and outstanding shares of preferred stock of any of such Person’s Subsidiaries in the event of any voluntary or involuntary liquidation, dissolution or winding up (excluding any such preference attributable to such shares of preferred stock that are owned by such Person or any of its Subsidiaries; provided, that if such Person is the Company, such exclusion shall be for such preference attributable to such shares of preferred stock that are owned by the Company or any of its Subsidiaries); and
|
(g)
|
any and all deferrals, renewals, extensions, refinancings and refundings (whether direct or indirect) of, or amendments, modifications or supplements to, any liability of the kind described in any of the preceding clauses (a), (b), (c), (d), (e), (f) or this clause (g), whether or not between or among the same parties. Subject to clause (c) of the preceding sentence, neither Dollar-Denominated Production Payments nor Volumetric Production Payments shall be deemed to be Indebtedness.
|
(i)
|
Liens existing on the issue date;
|
(ii)
|
Liens securing Indebtedness under Credit Facilities;
|
(iii)
|
Liens now or hereafter securing any Interest Rate Hedging Agreements so long as the related Indebtedness (a) constitutes the Existing Notes or the Securities (or any Permitted Company Refinancing Indebtedness in respect thereof) or (b) is, or is permitted to be under the 2005 Indenture, secured by a Lien on the same property securing such interest rate hedging obligations;
|
(iv)
|
Liens securing Permitted Company Refinancing Indebtedness or Permitted Subsidiary Refinancing Indebtedness; provided, that such Liens extend to or cover only the property or assets currently securing the Indebtedness being refinanced and that the Indebtedness being refinanced was not incurred under the Credit Facilities;
|
(v)
|
Liens for taxes, assessments and governmental charges not yet delinquent or being contested in good faith and for which adequate reserves have been established to the extent required by GAAP;
|
(vi)
|
mechanics’, worker’s, materialmen’s, operators’ or similar Liens arising in the ordinary course of business;
|
(vii)
|
Liens in connection with worker’s compensation, unemployment insurance or other social security, old age pension or public liability obligations;
|
(viii)
|
Liens, deposits or pledges to secure the performance of bids, tenders, contracts (other than contracts for the payment of money), leases, public or statutory obligations, surety, stay, appeal, indemnity, performance or other similar bonds, or other similar obligations arising in the ordinary course of business;
|
(ix)
|
survey exceptions, encumbrances, easements or reservations of, or rights of others for, rights of way, zoning or other restrictions as to the use of real properties, and minor defects in title which, in the case of any of the foregoing, were not incurred or created to secure the payment of borrowed money or the deferred purchase price of property or services, and in the aggregate do not materially adversely affect the value of such properties or materially impair use for the purposes of which such properties are held by the Company or any Subsidiaries;
|
(x)
|
Liens on, or related to, properties to secure all or part of the costs incurred in the ordinary course of business of exploration, drilling, development or operation thereof;
|
(xi)
|
Liens on pipeline or pipeline facilities which arise out of operation of law;
|
(xii)
|
judgment and attachment Liens not giving rise to an Event of Default or Liens created by or existing from any litigation or legal proceeding that are currently being contested in good faith by appropriate proceedings and for which adequate reserves have been made;
|
(xiii)
|
(a) Liens upon any property of any Person existing at the time of acquisition thereof by the Company or a Subsidiary, (b) Liens upon any property of a Person existing at the time such Person is merged or consolidated with the Company or any Subsidiary or existing at the time of the sale or transfer of any such property of such Person to the Company or any Subsidiary, or (c) Liens upon any property of a Person existing at the time such Person becomes a Subsidiary; provided, that in each case such Lien has not been created in contemplation of such sale, merger, consolidation, transfer or acquisition, and provided, further, that in each such case no such Lien shall extend to or cover any property of the Company or any Subsidiary other than the property being acquired and improvements thereon;
|
(xiv)
|
Liens on deposits to secure public or statutory obligations or in lieu of surety or appeal bonds entered into in the ordinary course of business;
|
(xv)
|
Liens in favor of collecting or payor banks having a right of setoff, revocation, refund or chargeback with respect to money or instruments of the Company or any Subsidiary on deposit with or in possession of such bank;
|
(xvi)
|
purchase money security interests granted in connection with the acquisition of assets in the ordinary course of business and consistent with past practices, provided, that (A) such Liens attach only to the property so acquired with the purchase money indebtedness secured thereby and (B) such Liens secure only Indebtedness that is not in excess of 100% of the purchase price of such assets;
|
(xvii)
|
Liens reserved in oil and gas mineral leases for bonus or rental payments and for compliance with the terms of such leases;
|
(xviii)
|
Liens arising under partnership agreements, oil and gas leases, farm-out agreements, division orders, contracts for the sale, purchase, exchange, transportation or processing (but not refining) of oil, gas or other hydrocarbons, unitization and pooling declarations and agreements, development agreements, operating agreements, area of mutual interest agreements, and other similar agreements which are customary in the Oil and Gas Business;
|
(xix)
|
Liens securing obligations of the Company or any of its Subsidiaries under Currency Hedge Obligations or Oil and Gas Hedging Contracts;
|
(xx)
|
Liens to secure Dollar-Denominated Production Payments and Volumetric Production Payments; and
|
(xxi)
|
Liens securing other Indebtedness in an aggregate principal amount which, together with all other Indebtedness outstanding on the date of such incurrence and secured by Liens pursuant to this clause (xxi), does not exceed 15% of Adjusted Consolidated Tangible Net Assets.
|
|
|
Exhibit 21
|
|
||
Limited Liability Companies
|
|
State of Organization
|
Brazos Valley Longhorn, L.L.C.
|
|
Delaware
|
Chesapeake Appalachia, L.L.C.
|
|
Oklahoma
|
Chesapeake Energy Louisiana, LLC
|
|
Oklahoma
|
Chesapeake Exploration, L.L.C.
|
|
Oklahoma
|
Chesapeake Land Development Company, L.L.C.
|
|
Oklahoma
|
Chesapeake Operating, L.L.C.
|
|
Oklahoma
|
WHR Eagle Ford LLC
|
|
Delaware
|
|
|
|
Partnerships
|
|
State of Organization
|
Chesapeake Louisiana, L.P.
|
|
Oklahoma
|
|
|
|
* In accordance with Regulation S-K Item 601(b)(21), the names of particular subsidiaries that, considered in the aggregate as a single subsidiary, would not constitute a significant subsidiary (as that term is defined in Rule 1-02(w) of Regulation S-X) as of the end of the year covered by this report have been omitted.
|
|
|
Exhibit 23.1
|
CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
|
||||
|
|
|
|
|
We hereby consent to the incorporation by reference in the Registration Statements on Form S-8 (File Nos. 333-126191, 333-135949, 333-143990, 333-151762, 333-160350, 333-171468, 333-178067, 333-187018, 333-189651, 333-192175, 333-196977 and 333-216483) and Form S-3 (File No. 333-219649) of Chesapeake Energy Corporation of our report dated February 27, 2020 relating to the financial statements and the effectiveness of internal control over financial reporting, which appears in this Form 10‑K.
|
||||
|
|
|
|
|
/s/ PricewaterhouseCoopers LLP
|
|
|
||
|
|
|
||
Oklahoma City, Oklahoma
|
|
|
||
February 27, 2020
|
|
|
|
|
Exhibit 23.2
|
|
|
Exhibit 31.1
|
1.
|
I have reviewed this Annual Report on Form 10-K of Chesapeake Energy Corporation;
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
(a)
|
designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
(b)
|
designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
(c)
|
evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
(d)
|
disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
|
5.
|
The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
|
(a)
|
all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
|
(b)
|
any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
|
February 27, 2020
|
By:
|
/s/ ROBERT D. LAWLER
|
|
|
Robert D. Lawler
|
|
|
President and Chief Executive Officer
|
|
|
Exhibit 31.2
|
1.
|
I have reviewed this Annual Report on Form 10-K of Chesapeake Energy Corporation;
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
(a)
|
designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
(b)
|
designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
(c)
|
evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
(d)
|
disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
|
5.
|
The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
|
(a)
|
all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
|
(b)
|
any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
|
February 27, 2020
|
By:
|
/s/ DOMENIC J. DELL'OSSO, JR.
|
|
|
Domenic J. Dell'Osso, Jr.
|
|
|
Executive Vice President and Chief Financial Officer
|
|
|
Exhibit 32.1
|
1.
|
The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
|
2.
|
The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.
|
February 27, 2020
|
By:
|
/s/ ROBERT D. LAWLER
|
|
|
Robert D. Lawler
|
|
|
President and Chief Executive Officer
|
|
|
Exhibit 32.2
|
1.
|
The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
|
2.
|
The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.
|
February 27, 2020
|
By:
|
/s/ DOMENIC J. DELL'OSSO, JR.
|
|
|
Domenic J. Dell'Osso, Jr.
|
|
|
Executive Vice President and Chief Financial Officer
|
Software Integrated Solutions
Division of Schlumberger Technology Corporation
|
Exhibit 99.1
|
||
|
|
|
|
4600 J. Barry Court
Suite 200
Canonsburg, Pennsylvania 15317 USA
Tel: +1-724-416-9700
Fax: +1-724-416-9705
|
|
||
|
|
|
|
|
|
Proved
Developed
Reserves
|
Proved
Undeveloped
Reserves
|
|
Total
Proved
Reserves
|
|
Remaining Net Reserves
|
|
|
|
|
|
|
Oil – Mbbls
|
|
146,834.41
|
119,126.48
|
|
265,960.89
|
|
NGL – Mbbls
|
|
57,711.56
|
23,589.66
|
|
81,301.21
|
|
Gas – MMscf
|
|
2,748,500.69
|
2,814,084.61
|
|
5,562,585.29
|
|
Oil Equiv. – Mbbls
|
|
662,629.41
|
611,730.24
|
|
1,274,359.65
|
|
|
|
|
|
|
|
|
Income Data (M$)
|
|
|
|
|
|
|
Future Net Revenue
|
|
12,309,379.32
|
11,396,730.92
|
|
23,706,110.24
|
|
Deductions
|
|
|
|
|
|
|
Operating Expense
|
|
2,395,252.39
|
1,034,215.53
|
|
3,429,467.92
|
|
Production Taxes
|
|
771,737.40
|
570,950.89
|
|
1,342,688.28
|
|
Abandonment Expense
|
|
232,332.35
|
58,416.22
|
|
290,748.57
|
|
Investment
|
|
7,258.18
|
3,972,430.49
|
|
3,979,688.66
|
|
Future Net Cashflow (FNC)
|
|
8,902,798.97
|
5,760,717.78
|
|
14,663,516.75
|
|
|
|
|
|
|
|
|
Discounted PV @ 10% (M$)
|
|
5,281,433.95
|
2,374,831.18
|
|
7,656,265.12
|
|
Software Integrated Solutions
Division of Schlumberger Technology Corporation
4 February 2020
Page 2
|
|
|
Proved
Producing
Reserves
|
|
Proved
NonProducing
Reserves
|
|
Proved
Shut-In
Reserves
|
|
Proved
Undeveloped
Reserves
|
|
Total
Proved
Reserves
|
|
Remaining Net Reserves
|
|
|
|
|
|
|
|
|
|
|
Oil – Mbbls
|
146,597.73
|
|
236.68
|
|
0.00
|
|
119,126.48
|
|
265,960.89
|
|
NGL – Mbbls
|
57,654.10
|
|
57.46
|
|
0.00
|
|
23,589.66
|
|
81,301.21
|
|
Gas – MMscf
|
2,726,246.78
|
|
22,253.91
|
|
0.00
|
|
2,814,084.61
|
|
5,562,585.29
|
|
Oil Equiv. – Mbbls
|
658,626.29
|
|
4,003.12
|
|
0.00
|
|
611,730.24
|
|
1,274,359.65
|
|
|
|
|
|
|
|
|
|
|
|
|
Income Data (M$)
|
|
|
|
|
|
|
|
|
|
|
Future Net Revenue
|
12,262,764.28
|
|
46,615.03
|
|
0.01
|
|
11,396,730.92
|
|
23,706,110.24
|
|
Deductions
|
|
|
|
|
|
|
|
|
|
|
Operating Expense
|
2,387,026.03
|
|
8,054.19
|
|
172.17
|
|
1,034,215.53
|
|
3,429,467.92
|
|
Production Taxes
|
769,618.96
|
|
2,118.43
|
|
0.00
|
|
570,950.89
|
|
1,342,688.28
|
|
Abandonment Expense
|
222,097.84
|
|
1,235.87
|
|
8,998.64
|
|
58,416.22
|
|
290,748.57
|
|
Investment
|
0.00
|
|
7,258.18
|
|
0.00
|
|
3,972,430.49
|
|
3,979,688.66
|
|
Future Net Cashflow (FNC)
|
8,884,021.41
|
|
27,948.37
|
|
-9,170.80
|
|
5,760,717.78
|
|
14,663,516.75
|
|
|
|
|
|
|
|
|
|
|
|
|
Discounted PV @ 10% (M$)
|
5,270,033.17
|
|
15,014.18
|
|
-3,613.40
|
2,374,831.18
|
|
7,656,265.12
|
|
Software Integrated Solutions
Division of Schlumberger Technology Corporation
4 February 2020
Page 3
|
|
Product
|
Reference Point
|
Year End 2019
Reference Price
|
Average
Price
|
Oil
|
West Texas Intermediate
|
$55.69/Bbl
|
$56.53/Bbl
|
NGL
|
West Texas Intermediate
|
$55.69/Bbl
|
$10.26/Bbl
|
Natural Gas
|
Henry Hub
|
$2.58/MMBtu
|
$1.41/Mscf
|
Software Integrated Solutions
Division of Schlumberger Technology Corporation
4 February 2020
Page 4
|
|
/s/ Denise L. Delozier
|
|
/s/ Charles M. Boyer II
|
Denise L. Delozier
Principal Reservoir Engineer
|
|
Charles M. Boyer II, PG, CPG
Advisor - Unconventional Reservoirs
Technical Team Leader
|