Le Lézard
Classified in: Business, Covid-19 virus
Subjects: EARNINGS, Conference Call, Webcast, Stock Sale/Buyback

California Resources Reports First Quarter 2022 Results, Increases and Extends Its Share Repurchase Program, Raises 2022 Guidance and Provides an Update on Its Carbon Management Business


California Resources Corporation (NYSE: CRC), an independent oil and natural gas company committed to energy transition in the sector, today reported first quarter 2022 operational and financial results.

"CRC began 2022 on a good note as we continued to deliver strong operational results. Given our continued robust free cash flow generation and pristine balance sheet, we are increasing our share repurchase program by $300 million to $650 million in total, adding one drilling rig at our Wilmington Field and raising our full year guidance," said Mac McFarland, President and Chief Executive Officer.

Mr. McFarland continued, "We are further advancing our energy transition efforts by filing additional EPA Class VI permits on 80 million metric tons of carbon dioxide (CO2) permanent storage and expanding our carbon storage network to the San Francisco Bay Area. Additionally, we are pleased to announce that we are progressing our CalCapture project. We have engaged Next Carbon Solutions to conduct a second front-end engineering and design study to explore the decarbonization of our Elk Hills power plant and the potential to produce California's first "Net Zero" barrel. This project is estimated to capture up to 28 million metric tons of CO2 over its 20 year project life, the equivalent emissions of more than 300,000 gas-fueled passenger vehicles per year. This opportunity further highlights our continued focus on lowering our emissions and advancing our ESG goals to demonstrate leadership in the energy transition."

Primary Highlights

First Quarter 2022 Highlights

Financial

Operations

2022 Production Guidance & Capital Program Update3

CRC is increasing its 2022 capital program to a range of $340 to $385 million from $330 million to $375 million. For CRC's oil and natural gas operations, in response to the continued strong commodity environment, CRC increased its capital program to add one rig at its Wilmington Field. This additional rig is expected to generate IRR's of above 160% and paybacks of approximately one year. For CRC's carbon management activities, CRC decreased its capital program to remove approximately $20 million for purchases of properties, land easements and leases. These amounts will be reported separately from its 2022 capital program in its condensed consolidated financial statements. This level of expected spending is consistent with CRC's strategy of investing up to 50% of its operating cash flow back into its oil and gas operations and targeting investing approximately 25% of its operating cash flow in carbon management projects over the next several years.

With this capital program, CRC expects to maintain oil production flat from exit to exit and is increasing its production guidance to 91,000 to 94,000 BOE per day. CRC plans to run five drilling rigs in the Mount Poso, Elk Hills, Buena Vista and Wilmington fields, and will focus on high return oil opportunities and continue to build off of the success of the 2021 drilling program.

In addition, CRC is raising its free cash flow1 and adjusted EBITDAX1 guidance by 17% and 11% at the midpoint, respectively, to $330 to $410 million and $860 to $960 million.

As a result of higher prices for purchased natural gas, which CRC uses to generate electricity for its operations, and for purchased electricity, the company is also raising its operating cost guidance to $680 to $720 million from $640 to $670 million.

 

 

 

 

 

 

TOTAL CRC GUIDANCE3

2022E

 

CMB 2022E

 

E&P, Corp. & Other
2022E

Net Total Production (MBoe/d)

94 - 91

 

 

 

94 - 91

Net Oil Production (MBbl/d)

61 - 57

 

 

 

61 - 57

Operating Costs ($ millions)

$680 - $720

 

 

 

$680 - $720

CMB Expenses4 ($ millions)

$45 - $55

 

$45 - $55

 

 

Adjusted General and Administrative Expenses1 ($ millions)

$165 - $190

 

$10 - $15

 

$155 - $175

Total Capital ($ millions)

$340 - $385

 

$15 - $25

 

$325 - $360

Drilling & Completions

$240 - $250

 

 

 

$240 - $250

Workovers

$25 - $35

 

 

 

$25 - $35

Facilities

$55 - $65

 

 

 

$55 - $65

Corporate & Other

$5 - $10

 

 

 

$5 - $10

Carbon Management Business

$15 - $25

 

$15 - $25

 

 

Adjusted EBITDAX1 ($ millions)

$860 - $960

 

($55) - ($70)

 

$930 -- $1,015

Free Cash Flow1 ($ millions)

$330 - $410

 

($70) - ($95)

 

$425 - $480

Carbon Management Business (CMB) Update

In May 2022, CRC applied for two Class VI permits for an additional 80 million metric tons of permanent CO2 storage for two new Carbon TerraVault carbon capture and storage (CCS) projects in the Sacramento basin, which, subject to approval, brings its total potential permitted storage to 120 million metric tons. This puts CRC over halfway to its target of applying for 200 million metric tons of permanent CO2 storage for Carbon TerraVault CCS projects by the end of 2022.

During the first quarter of 2022, CRC spent approximately $2 million for CMB expenses related to Carbon TerraVault projects and approximately $1 million of capital on these projects. In addition, CRC acquired properties and land easements for carbon management activities. Total spend for these carbon-related acquisitions was $17 million.

CalCapture CCS+ Update

In April 2022, CRC entered into an agreement with NEXT Carbon Solutions (NCS), a subsidiary of NextDecade Corporation, to further explore the decarbonization of CRC's Elk Hills power plant through the application of NCS' proprietary post-combustion carbon capture processes for its CalCapture CCS+ project. Pursuant to this agreement, NCS will perform a FEED study for the post combustion capture and compression of up to 95% of the CO2 produced at the Elk Hills power plant. CRC expects this FEED study to commence in the second quarter of 2022 and it is projected to take approximately six months to complete. NCS previously delivered a front-end loading stage 2 analysis (FEL-2) to CRC which provided improved project prospects from technical and economic perspectives for the CalCapture CCS+ project. CRC and NCS expect to finalize definitive commercial documents allowing the CalCapture CCS+ project to proceed with a final investment decision following the completion and the review of the FEED. The CalCapture CCS+ project targets initial injection of 1.4 million metric tons of CO2 per year and is projected to average approximately 7,000 incremental barrels of "Net Zero" oil per day over the life of project.

Sustainability Update

CRC continues to prioritize its Environmental, Social, and Governance (ESG) initiatives and make progress toward its Full-Scope Net Zero goal by 2045. CRC defines Full-Scope Net Zero as achieving permanent storage of captured or removed carbon emissions in a volume equal to all of its scope 1, 2, and 3 emissions by 2045 through a variety of opportunities with an "all-of-the-above" strategy which includes CalCapture CCS+, Carbon TerraVault and other emissions reduction projects.

In April 2022, CRC updated and expanded its ESG goals that build upon CRC's long-standing commitment to sustainability. CRC's ESG goals focus on providing low carbon intensity fuel today and net zero fuel for the future that meets or exceeds California's unparalleled sustainability standards ? not only related to lowering greenhouse gas (GHG) emissions, but also to further decreasing methane emissions, reducing freshwater consumption, expanding leadership diversity, enhancing community engagement, and increasing accountability by linking executive compensation to ESG performance.

"CRC's ESG goals demonstrate our commitment to the energy transition, and we are proud that CRC successfully continues on a path to provide safe and reliable low carbon intensity fuel and develop carbon capture and storage and other emissions reducing projects," said Mac McFarland, CRC President and Chief Executive Officer.

First Quarter 2022 E&P Operational Results

Total daily net production for the first quarter of 2022, compared to the fourth quarter of 2021, decreased by approximately 9,000 BOE per day, or 9%. During the first quarter of 2022, a planned 10-year maintenance turnaround occurred at a cryogenic gas processing facility, and was completed safely, successfully and ahead of schedule. This maintenance reduced total daily net natural gas and NGL production for the first quarter of 2022 by approximately 5,000 BOE per day. Production was also affected by the divestiture of CRC's remaining 50% working interest in certain zones in the Lost Hills field in February 2022 and CRC's divestiture of its Ventura basin operations beginning in the fourth quarter of 2021 which reduced CRC's total net production by approximately 3,000 BOE per day for the first quarter of 2022 compared to the fourth quarter of 2021. CRC's production also decreased as a result of natural decline, which was partially offset by improved operational results from its developmental drilling. CRC's production-sharing contracts (PSCs) had a similar impact on its net oil production in the first quarter of 2022 compared to the fourth quarter of 2021.

During the first quarter of 2022, CRC operated an average of three drilling rigs in the San Joaquin Basin and one drilling rig in the Los Angeles Basin. CRC's drilling program continues to see IRR's of above 100%. During the quarter, CRC drilled 42 net wells and brought online 40 wells. See Attachment 3 for further information on CRC's production results by basin and Attachment 5 for further information on CRC's drilling activity.

First Quarter 2022 Financial Results

 

1st Quarter

 

 

4th Quarter

($ and shares in millions, except per share amounts)

2022

 

 

2021

 

 

 

 

 

Statements of Operations:

 

 

 

 

Revenues

 

 

 

 

Total operating revenues

$

153

 

 

 

$

634

 

 

 

 

 

Operating Expenses

 

 

 

 

Total operating expenses

 

396

 

 

 

 

422

Gain on asset divestitures

 

54

 

 

 

 

120

Operating Income (Loss)

$

(189

)

 

 

$

332

Net Income (Loss) Attributable to Common Stock

$

(175

)

 

 

$

714

 

 

 

 

 

Net income (loss) attributable to common stock per share - basic

$

(2.23

)

 

 

$

8.91

Net income (loss) attributable to common stock per share - diluted

$

(2.23

)

 

 

$

8.71

Adjusted net income (loss)1

$

91

 

 

 

$

175

Adjusted net income (loss)1 per share - diluted

$

1.13

 

 

 

$

2.13

Weighted-average common shares outstanding - basic

 

78.5

 

 

 

 

80.1

Weighted-average common shares outstanding - diluted

 

78.5

 

 

 

 

82.0

Adjusted EBITDAX1

$

206

 

 

 

$

260

 

1st Quarter

 

 

4th Quarter

($ in millions)

2022

 

 

2021

Cash Flow Data:

 

 

 

 

Net cash provided by operating activities

$

160

 

 

 

$

204

 

Net cash used in investing activities

$

(53

)

 

 

$

(10

)

Net cash used in financing activities

$

(84

)

 

 

$

(78

)

Review of First Quarter 2022 Financial Results

Realized oil prices, excluding the effects of cash settlements on CRC's commodity derivative contracts, increased by $17.14 per barrel from $78.99 per barrel in the fourth quarter of 2021 to $96.13 per barrel in the first quarter of 2022. Realized oil prices were higher in the first quarter of 2022 compared to the fourth quarter of 2021 as the effects of the COVID-19 pandemic have subsided leaving crude oil production and product inventories at historically low levels. As demand has rebounded, producers have generally maintained capital discipline, OPEC+ members have failed to produce at stepped-up quotas, and the conflict between Russia and Ukraine has created a disconnect between buyers and sellers of Russian produced crude oil. Realized oil prices, including the effects of cash settlements on CRC's commodity derivative contracts, decreased by $0.70 from $61.00 to $60.30. The reason for the decrease is due to higher settlement payments on CRC's commodity derivative contracts caused by the higher commodity price environment in the first quarter of 2022 compared to the fourth quarter of 2021. See Attachment 4 for further information on prices.

Adjusted EBITDAX1 for the first quarter of 2022 was $206 million. See table below for the Company's net cash provided by operating activities, capital investments and free cash flow1 during the same periods.

FREE CASH FLOW1

 

 

 

 

 

 

 

 

 

 

 

Management uses free cash flow, which is defined by us as net cash provided by operating activities less capital investments, as a measure of liquidity. The following table presents a reconciliation of our net cash provided by operating activities to free cash flow. We have excluded one-time costs for bankruptcy related fees during 2021 and 2020 as a supplemental measure of free cash flow.

 

 

 

 

 

 

 

 

1st Quarter

 

 

4th Quarter

($ millions)

 

2022

 

 

2021

 

 

 

 

 

 

Net cash provided by operating activities

 

$

160

 

 

 

$

204

 

Capital investments

 

 

(99

)

 

 

 

(66

)

Free cash flow1

 

$

61

 

 

 

$

138

 

The following table presents key operating data for CRC's oil and gas operations, on a per BOE basis, for the periods presented below. Energy operating costs consist of purchases of natural gas used to generate electricity, purchased electricity and internal costs to generate electricity used in CRC's operations. Non-energy operating costs equal total operating costs less energy and gas processing costs. However, non-energy operating costs include the costs of purchasing natural gas to generate steam for its steamfloods.

OPERATING COSTS PER BOE

 

 

 

 

 

 

The reporting of our PSCs creates a difference between reported operating costs, which are for the full field, and reported volumes, which are only our net share, inflating the per barrel operating costs. The following table presents operating costs after adjusting for the excess costs attributable to PSCs.

 

 

 

 

 

 

 

 

1st Quarter

 

 

4th Quarter

($ per Boe)

 

2022

 

 

2021

Energy operating costs

 

$

6.68

 

 

 

$

5.47

 

Gas processing costs

 

 

0.56

 

 

 

 

0.41

 

Non-energy operating costs

 

 

15.63

 

 

 

 

14.57

 

Operating costs

 

$

22.87

 

 

 

$

20.45

 

Excess costs attributable to PSCs

 

 

(2.30

)

 

 

 

(2.13

)

Operating costs, excluding effects of PSCs (a)

 

$

20.57

 

 

 

$

18.32

 

 

 

 

 

 

 

(a) Operating costs, excluding effects of PSCs is a non-GAAP measure.

Energy operating costs for the first quarter of 2022 were $53 million, or $6.68 per BOE, which was an increase of $5 million or 10% from $48 million, or $5.47 per BOE, for the fourth quarter of 2021. This increase was primarily a result of higher prices for purchased natural gas, which CRC used to generate electricity for its operations, and for purchased electricity. Energy operating costs were also higher on a per BOE basis as a result of lower production volumes between periods.

Non-energy operating costs for the first quarter of 2022 were $124 million, or $15.63 per BOE, which was a decrease of $6 million or 5% from $130 million, or $14.57 per BOE, for the fourth quarter of 2021. This decrease was primarily a result of reduced downhole maintenance activity and reduced volumes of natural gas purchased for use in CRC's steamflood operations. The per BOE increase was primarily due to lower production volumes between periods.

Balance Sheet and Liquidity Update

CRC's aggregate commitment under the Revolving Credit Facility was $552 million as of March 31, 2022. This amount includes $60 million of additional commitments from new lenders that CRC obtained in February 2022. The borrowing base for the Revolving Credit Facility is redetermined semi-annually and was reaffirmed at $1.2 billion on April 29, 2022.

On April 29, 2022, CRC amended its Revolving Credit Facility to, among other things, modify the minimum hedge requirement and the restricted payment contained in the Revolving Credit Facility. As a result of this amendment, the rolling hedge requirement as described in Part II, Item 8 ? Financial Statements and Supplementary Data, Note 4 Debt in CRC's 2021 Annual Report has been modified. Furthermore, the restricted payment and investments covenants were modified to permit unlimited restricted payments and/or investments so long as (i) no Default, Event of Default or Borrowing Base Deficiency shall have occurred and be continuing under the Revolving Credit Facility at the time of such investment or restricted payment, (ii) the undrawn availability under the Revolving Credit Facility is not less than 30.0% at such time and (iii) the Consolidated Total Net Leverage Ratio is less than or equal to 1.50 to 1.00.

As of March 31, 2022, CRC had liquidity of $744 million, which consisted of $328 million in cash and $416 million of available borrowing capacity under its Revolving Credit Facility.

Acquisitions and Divestitures

During the first quarter of 2022, CRC recorded a gain of $6 million related to the sale of certain Ventura basin assets. CRC expects to divest its remaining assets in the Ventura basin during the second half of 2022, pending final approval from the State Lands Commission.

On February 1, 2022, CRC sold its 50% non-operated working interest in certain horizons within its Lost Hills field, located in the San Joaquin basin, recognizing a gain of $49 million. CRC retained an option to capture, transport and store 100% of the CO2 from steam generators across the Lost Hills field for future carbon management projects. CRC also retained 100% of the deep rights and related seismic data.

Shareholder Returns Strategy

CRC continues to prioritize shareholder returns and is committed to delivering approximately 25% of operating cash flow to shareholders. In light of this strategy, CRC increased the Share Repurchase Program by $300 million to $650 million and extended the term of the program through June 30, 2023. After the repurchases through April 29, 2022, and the $300 million increase, CRC has $411 million available for future potential share repurchases.

During the first quarter of 2022, CRC repurchased approximately 1.7 million shares of its common stock for $71 million. Since the inception of Share Repurchase Program through April 29, 2022, CRC has repurchased 6.2 million shares for $239 million.

On May 4, 2022, CRC's Board of Directors declared a quarterly dividend of $0.17 per share of common stock. The dividend is payable to shareholders of record on June 1, 2022, and will be paid on June 16, 2022.

Upcoming Investor Conference Participation

CRC's executives will be participating in the following virtual and in-person events in May 2022 and June 2022:

CRC's presentation materials will be available the day of the events on the Events and Presentations page in the Investor Relations section on www.crc.com.

Conference Call Details

To participate in the conference call scheduled for later today at 1:00 p.m. Eastern Time, please dial (877) 328-5505 (International calls please dial +1 (412) 317-5421) or access via webcast at www.crc.com 15 minutes prior to the scheduled start time to register. Participants may also pre-register for the conference call at https://dpregister.com/sreg/10164563/f1eff7c58f. A digital replay of the conference call will be archived for approximately 90 days and supplemental slides for the conference call will be available online in the Investor Relations section of www.crc.com.

1

 

See Attachment 2 for the non-GAAP financial measures of adjusted EBITDAX, operating costs per BOE (excluding effects of PSCs), adjusted net income (loss), adjusted net income (loss) per share - basic and diluted), free cash flow and free cash flow, after special items including reconciliations to their most directly comparable GAAP measure, where applicable. For the full year 2022 estimates of the non-GAAP measures of adjusted EBITDAX and free cash flow, including reconciliations to their most directly comparable GAAP measure, see Attachment 7.

2

 

Calculated as $328 million of cash plus $552 million of capacity on CRC's Revolving Credit Facility less $136 million in outstanding letters of credit

3

 

2022 guidance assumes a 2022 Brent price of $98 per barrel of oil, NGL realizations consistent with prior years and a NYMEX gas price of $5.30 per mcf. CRC's share of production under PSC contracts decreases when commodity prices rise and increases when prices fall.

4

 

CMB Expenses include start-up expenditures.

About California Resources Corporation

California Resources Corporation (CRC) is an independent oil and natural gas company committed to energy transition in the sector. CRC has some of the lowest carbon intensity production in the US and we are focused on maximizing the value of our land, mineral and technical resources for decarbonization by developing carbon capture and storage (CCS) and other emissions reducing projects. For more information about CRC, please visit www.crc.com.

Forward-Looking Statements

This document contains statements that we believe to be "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements other than historical facts are forward-looking statements, and include statements regarding CRC's future financial position, business strategy, projected revenues, earnings, costs, capital expenditures and plans and objectives of management for the future. Words such as "expect," "could," "may," "anticipate," "intend," "plan," "ability," "believe," "seek," "see," "will," "would," "estimate," "forecast," "target," "guidance," "outlook," "opportunity" or "strategy" or similar expressions are generally intended to identify forward-looking statements. Such forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those expressed in, or implied by, such statements.

Although we believe the expectations and forecasts reflected in CRC's forward-looking statements are reasonable, they are inherently subject to numerous risks and uncertainties, most of which are difficult to predict and many of which are beyond CRC's control. No assurance can be given that such forward-looking statements will be correct or achieved or that the assumptions are accurate or will not change over time. Particular uncertainties that could cause our actual results to be materially different than those expressed in CRC's forward-looking statements include:

CRC cautions you not to place undue reliance on forward-looking statements contained in this document, which speak only as of the filing date, and CRC undertakes no obligation to update this information. This document may also contain information from third party sources. This data may involve a number of assumptions and limitations, and we have not independently verified them and do not warrant the accuracy or completeness of such third-party information.

Attachment 1

SUMMARY OF RESULTS

 

 

 

 

 

 

 

 

 

 

 

 

1st Quarter

 

4th Quarter

 

1st Quarter

($ and shares in millions, except per share amounts)

2022

 

2021

 

2021

 

 

 

 

 

 

Statements of Operations:

 

 

 

 

 

Revenues

 

 

 

 

 

Oil, natural gas and NGL sales

$

628

 

 

$

589

 

 

$

432

 

Net loss from commodity derivatives

 

(562

)

 

 

(73

)

 

 

(213

)

Sales of purchased natural gas

 

32

 

 

 

71

 

 

 

98

 

Electricity sales

 

34

 

 

 

41

 

 

 

33

 

Other revenue

 

21

 

 

 

6

 

 

 

13

 

Total operating revenues

 

153

 

 

 

634

 

 

 

363

 

 

 

 

 

 

 

Operating Expenses

 

 

 

 

 

Operating costs

 

182

 

 

 

182

 

 

 

164

 

General and administrative expenses

 

48

 

 

 

53

 

 

 

48

 

Depreciation, depletion and amortization

 

49

 

 

 

53

 

 

 

52

 

Asset impairments

 

?

 

 

 

?

 

 

 

3

 

Taxes other than on income

 

34

 

 

 

32

 

 

 

40

 

Exploration expense

 

1

 

 

 

1

 

 

 

2

 

Purchased natural gas expense

 

21

 

 

 

52

 

 

 

61

 

Electricity generation expenses

 

24

 

 

 

26

 

 

 

24

 

Transportation costs

 

12

 

 

 

14

 

 

 

12

 

Accretion expense

 

11

 

 

 

11

 

 

 

13

 

Other operating expenses, net

 

14

 

 

 

(2

)

 

 

17

 

Total operating expenses

 

396

 

 

 

422

 

 

 

436

 

Net gain on asset divestitures

 

54

 

 

 

120

 

 

 

?

 

Operating (Loss) Income

 

(189

)

 

 

332

 

 

 

(73

)

 

 

 

 

 

 

Non-Operating (Expenses) Income

 

 

 

 

 

Reorganization items, net

 

?

 

 

 

(1

)

 

 

(2

)

Interest and debt expense, net

 

(13

)

 

 

(14

)

 

 

(13

)

Net loss on early extinguishment of debt

 

?

 

 

 

?

 

 

 

(2

)

Other non-operating expenses, net

 

1

 

 

 

1

 

 

 

1

 

 

 

 

 

 

 

Net (Loss) Income Before Income Taxes

 

(201

)

 

 

318

 

 

 

(89

)

Income taxes

 

26

 

 

 

396

 

 

 

?

 

Net (loss) income

 

(175

)

 

 

714

 

 

 

(89

)

Net income attributable to noncontrolling interests

 

?

 

 

 

?

 

 

 

(5

)

Net (Loss) Income Attributable to Common Stock

$

(175

)

 

$

714

 

 

$

(94

)

 

 

 

 

 

 

Net income (loss) attributable to common stock per share - basic

$

(2.23

)

 

$

8.91

 

 

$

(1.13

)

Net income (loss) attributable to common stock per share - diluted

$

(2.23

)

 

$

8.71

 

 

$

(1.13

)

 

 

 

 

 

 

Adjusted net income (loss)

$

91

 

 

$

175

 

 

$

102

 

Adjusted net income (loss) per share - basic

$

1.16

 

 

$

2.18

 

 

$

1.22

 

Adjusted net income (loss) per share - diluted

$

1.13

 

 

$

2.13

 

 

$

1.22

 

 

 

 

 

 

 

Weighted-average common shares outstanding - basic

 

78.5

 

 

 

80.1

 

 

 

83.3

 

Weighted-average common shares outstanding - diluted

 

78.5

 

 

 

82.0

 

 

 

83.3

 

 

 

 

 

 

 

Adjusted EBITDAX

$

206

 

 

$

260

 

 

$

189

 

Effective tax rate

 

13

%

 

 

(125

) %

 

 

0

%

1st Quarter

 

4th Quarter

 

1st Quarter

($ in millions)

2022

 

2021

 

2021

Cash Flow Data:

 

 

 

 

 

Net cash provided by operating activities

$

160

 

 

$

204

 

 

$

147

 

Net cash used in investing activities

$

(53

)

 

$

(10

)

 

$

(20

)

Net cash used by financing activities

$

(84

)

 

$

(78

)

 

$

(25

)

 

March 31,

 

December 31,

($ and shares in millions)

2022

 

2021

 

 

 

 

Selected Balance Sheet Data:

 

 

 

Total current assets

$

834

 

$

753

Property, plant and equipment, net

$

2,643

 

$

2,599

Deferred tax asset

$

429

 

$

396

Total current liabilities

$

1,205

 

$

854

Long-term debt, net

$

590

 

$

589

Noncurrent asset retirement obligations

$

426

 

$

438

Stockholders' Equity

$

1,433

 

$

1,688

 

 

 

 

Outstanding shares

 

77.6

 

 

79.3

GAINS AND LOSSES FROM COMMODITY DERIVATIVES

 

 

 

 

 

 

 

 

 

1st Quarter

 

4th Quarter

 

1st Quarter

($ millions)

2022

 

2021

 

2021

 

 

 

 

 

 

Non-cash derivative (loss) gain

$

(381

)

 

$

26

 

 

$

(174

)

Net payments on settled commodity derivatives

 

(181

)

 

 

(99

)

 

 

(39

)

Net loss from commodity derivatives

$

(562

)

 

$

(73

)

 

$

(213

)

 

 

 

 

 

 

CAPITAL INVESTMENTS

 

 

 

 

 

 

 

 

 

1st Quarter

 

4th Quarter

 

1st Quarter

($ millions)

2022

 

2021

 

2021

 

 

 

 

 

 

Facilities

$

32

 

$

14

 

$

7

Drilling

 

59

 

 

46

 

 

13

Workovers

 

6

 

 

2

 

 

7

Total E&P capital

 

97

 

 

62

 

 

27

CMB

 

1

 

 

?

 

 

?

Other

 

1

 

 

4

 

 

?

Total capital program

$

99

 

$

66

 

$

27

 

 

 

 

 

 

Attachment 2

NON-GAAP FINANCIAL MEASURES AND RECONCILIATIONS

 

To supplement the presentation of its financial results prepared in accordance with U.S generally accepted accounting principles (GAAP), management uses certain non-GAAP measures to assess its financial condition, results of operations and cash flows. The non-GAAP measures include adjusted net income (loss), adjusted EBITDAX, adjusted EBITDAX margin, discretionary cash flow, free cash flow and operating costs per BOE, among others. These measures are also widely used by the industry, the investment community and our lenders. Although these are non-GAAP measures, the amounts included in the calculations were computed in accordance with GAAP. Certain items excluded from these non-GAAP measures are significant components in understanding and assessing our financial performance, such as our cost of capital and tax structure, as well as the effect of acquisition and development costs of our assets. Management believes that the non-GAAP measures presented, when viewed in combination with its financial and operating results prepared in accordance with GAAP, provide a more complete understanding of the factors and trends affecting the Company's performance. The non-GAAP measures presented herein may not be comparable to other similarly titled measures of other companies. Below are additional disclosures regarding each of the non-GAAP measures reported in this press release, including reconciliations to their most directly comparable GAAP measure where applicable.

 

 

 

 

 

 

 

 

 

 

ADJUSTED NET INCOME (LOSS)

 

 

 

 

 

 

Adjusted net income (loss) and adjusted net income (loss) per share are non-GAAP measures. We define adjusted net income as net income excluding the effects of significant transactions and events that affect earnings but vary widely and unpredictably in nature, timing and amount. These events may recur, even across successive reporting periods. Management believes these non-GAAP measures provide useful information to the industry and the investment community interested in comparing our financial performance between periods. Reported earnings are considered representative of management's performance over the long term. Adjusted net income (loss) is not considered to be an alternative to net income (loss) reported in accordance with GAAP. The following table presents a reconciliation of the GAAP financial measure of net income and net income attributable to common stock per share to the non-GAAP financial measure of adjusted net income (loss) and adjusted net income (loss) per share.

 

 

 

 

1st Quarter

 

4th Quarter

 

1st Quarter

($ millions, except per share amounts)

2022

 

2021

 

2021

Net (loss) income

$

(175

)

 

$

714

 

 

$

(89

)

Net income attributable to noncontrolling interests

 

?

 

 

 

?

 

 

 

(5

)

Net (loss) income attributable to common stock

 

(175

)

 

 

714

 

 

 

(94

)

Unusual, infrequent and other items:

 

 

 

 

 

Non-cash loss (income) from commodity derivatives

 

381

 

 

 

(26

)

 

 

174

 

Asset impairments

 

?

 

 

 

?

 

 

 

3

 

Reorganization items, net

 

?

 

 

 

1

 

 

 

2

 

Severance and termination costs

 

?

 

 

 

?

 

 

 

14

 

Net loss on early extinguishment of debt

 

?

 

 

 

?

 

 

 

2

 

Net gain on asset divestitures

 

(54

)

 

 

(120

)

 

 

(2

)

Rig termination expenses

 

?

 

 

 

?

 

 

 

1

 

Other, net

 

1

 

 

 

2

 

 

 

2

 

Total unusual, infrequent and other items

 

328

 

 

 

(143

)

 

 

196

 

Income tax provision of adjustments at effective tax rate

 

(93

)

 

 

?

 

 

 

?

 

Valuation allowance

 

31

 

 

 

(396

)

 

 

?

 

 

 

 

 

 

 

Adjusted net income attributable to common stock

$

91

 

 

$

175

 

 

$

102

 

 

 

 

 

 

 

Net (loss) income attributable to common stock per share - basic

$

(2.23

)

 

$

8.91

 

 

$

(1.13

)

Net (loss) income attributable to common stock per share - diluted

$

(2.23

)

 

$

8.71

 

 

$

(1.13

)

Adjusted net income per share - basic

$

1.16

 

 

$

2.18

 

 

$

1.22

 

Adjusted net income per share - diluted

$

1.13

 

 

$

2.13

 

 

$

1.22

 

 

 

 

 

 

 

FREE CASH FLOW

 

 

 

 

 

 

 

 

 

 

 

Management uses free cash flow, which is defined by us as net cash provided by operating activities less capital investments, as a measure of liquidity. The following table presents a reconciliation of our net cash provided by operating activities to free cash flow. We have excluded one-time costs for bankruptcy related fees during 2021 and 2020 as a supplemental measure of our free cash flow.

 

 

 

 

 

 

 

1st Quarter

 

4th Quarter

 

1st Quarter

($ millions)

2022

 

2021

 

2021

 

 

 

 

 

 

Net cash provided by operating activities

$

160

 

 

$

204

 

 

$

147

 

Capital investments

 

(99

)

 

 

(66

)

 

 

(27

)

Free cash flow

 

61

 

 

 

138

 

 

 

120

 

One-time bankruptcy related fees

 

?

 

 

 

1

 

 

 

2

 

Free cash flow, after special items

$

61

 

 

$

139

 

 

$

122

 

 

 

 

 

 

 

ADJUSTED EBITDAX

 

 

 

 

 

We define Adjusted EBITDAX as earnings before interest expense; income taxes; depreciation, depletion and amortization; exploration expense; other unusual, infrequent and out-of-period items; and other non-cash items. We believe this measure provides useful information in assessing our financial condition, results of operations and cash flows and is widely used by the industry, the investment community and our lenders. Although this is a non-GAAP measure, the amounts included in the calculation were computed in accordance with GAAP. Certain items excluded from this non-GAAP measure are significant components in understanding and assessing our financial performance, such as our cost of capital and tax structure, as well as depreciation, depletion and amortization of our assets. This measure should be read in conjunction with the information contained in our financial statements prepared in accordance with GAAP. A version of Adjusted EBITDAX is a material component of certain of our financial covenants under our Revolving Credit Facility and is provided in addition to, and not as an alternative for, income and liquidity measures calculated in accordance with GAAP.

 

 

 

 

 

1st Quarter

 

4th Quarter

 

1st Quarter

($ millions, except per BOE amounts)

2022

 

2021

 

2021

Net (loss) income

$

(175

)

 

$

714

 

 

$

(89

)

Interest and debt expense, net

 

13

 

 

 

14

 

 

 

13

 

Depreciation, depletion and amortization

 

49

 

 

 

53

 

 

 

52

 

Income taxes

 

(26

)

 

 

(396

)

 

 

?

 

Exploration expense

 

1

 

 

 

1

 

 

 

2

 

Unusual, infrequent and other items (a)

 

328

 

 

 

(143

)

 

 

196

 

Non-cash items

 

 

 

 

 

Accretion expense

 

11

 

 

 

11

 

 

 

13

 

Stock-based compensation

 

4

 

 

 

4

 

 

 

2

 

Post-retirement medical and pension

 

1

 

 

 

2

 

 

 

?

 

Other non-cash items

 

?

 

 

 

?

 

 

 

?

 

Adjusted EBITDAX

$

206

 

 

$

260

 

 

$

189

 

 

 

 

 

 

 

Net cash provided (used) by operating activities

$

160

 

 

$

204

 

 

$

147

 

Cash interest

 

23

 

 

 

2

 

 

 

3

 

Exploration expenditures

 

1

 

 

 

1

 

 

 

2

 

Working capital changes

 

22

 

 

 

53

 

 

 

37

 

Adjusted EBITDAX

$

206

 

 

$

260

 

 

$

189

 

 

 

 

 

 

 

Adjusted EBITDAX per Boe

$

25.89

 

 

$

29.22

 

 

$

21.12

 

 

 

 

 

 

 

(a) See Adjusted Net Income (Loss) reconciliation.

ADJUSTED GENERAL & ADMINISTRATIVE EXPENSES

 

 

 

 

 

 

Management uses a measure called adjusted general and administrative (G&A) expenses to provide useful information to investors interested in comparing our costs between periods and performance to our peers.

 

 

 

 

 

 

 

1st Quarter

 

4th Quarter

 

1st Quarter

($ millions)

2022

 

2021

 

2021

General and administrative expenses

$

48

 

 

$

53

 

 

$

48

 

Stock-based compensation

 

(4

)

 

 

(4

)

 

 

(2

)

Adjusted G&A expenses

$

44

 

 

$

49

 

 

$

46

 

 

 

 

 

 

 

OPERATING COSTS PER BOE

 

 

 

 

 

 

The reporting of our PSC-type contracts creates a difference between reported operating costs, which are for the full field, and reported volumes, which are only our net share, inflating the per barrel operating costs. The following table presents operating costs after adjusting for the excess costs attributable to PSCs.

 

 

 

 

 

 

 

1st Quarter

 

4th Quarter

 

1st Quarter

($ per BOE)

2022

 

2021

 

2021

Energy operating costs (1)

$

6.68

 

 

$

5.47

 

 

$

4.70

 

Gas processing costs

 

0.56

 

 

 

0.41

 

 

 

0.53

 

Non-energy operating costs (2)

 

15.63

 

 

 

14.57

 

 

 

13.10

 

Operating costs

$

22.87

 

 

$

20.45

 

 

$

18.33

 

 

 

 

 

 

 

Costs attributable to PSCs

 

 

 

 

 

Excess energy operating costs attributable to PSCs

$

(0.90

)

 

$

(0.82

)

 

$

(0.56

)

Excess non-energy operating costs attributable to PSCs

 

(1.40

)

 

 

(1.31

)

 

 

(1.05

)

Excess costs attributable to PSCs

$

(2.30

)

 

$

(2.13

)

 

$

(1.61

)

 

 

 

 

 

 

Energy operating costs, excluding effect of PSCs (1)

$

5.78

 

 

$

4.65

 

 

$

4.14

 

Gas processing costs, excluding effect of PSCs

 

0.56

 

 

 

0.41

 

 

 

0.53

 

Non-energy operating costs, excluding effect of PSCs (2)

 

14.23

 

 

 

13.26

 

 

 

12.05

 

Operating costs, excluding effects of PSCs

$

20.57

 

 

$

18.32

 

 

$

16.72

 

 

 

 

 

 

 

(1) Energy operating costs consist of purchases of natural gas to generate electricity, purchased electricity and internal costs to produce electricity used in our operations.

(2) Non-energy operating costs equal total operating costs less energy and gas processing costs. However, non-energy operating costs include the costs of purchasing natural gas used to generate steam for our steamfloods.

Attachment 3

PRODUCTION STATISTICS

 

 

 

 

 

Net

1st Quarter

 

4th Quarter

 

1st Quarter

Oil, NGLs and Natural Gas Production Per Day

2022

 

2021

 

2021

Oil (MBbl/d)

 

 

 

 

 

San Joaquin Basin

38

 

40

 

38

Los Angeles Basin

18

 

18

 

20

Ventura Basin

?

 

1

 

2

Total

56

 

59

 

60

 

 

 

 

 

 

NGLs (MBbl/d)

 

 

 

 

 

San Joaquin Basin

9

 

12

 

12

Total

9

 

12

 

12

 

 

 

 

 

 

Natural Gas (MMcf/d)

 

 

 

 

 

San Joaquin Basin

121

 

131

 

135

Los Angeles Basin

1

 

1

 

1

Ventura Basin

?

 

2

 

4

Sacramento Basin

19

 

19

 

20

Total

141

 

153

 

160

 

 

 

 

 

 

Total Production (MBoe/d)

88

 

97

 

99

 

 

 

 

 

 

Gross Operated and Net Non-Operated

1st Quarter

 

4th Quarter

 

1st Quarter

Oil, NGLs and Natural Gas Production Per Day

2022

 

2021

 

2021

Oil (MBbl/d)

 

 

 

 

 

San Joaquin Basin

43

 

45

 

44

Los Angeles Basin

26

 

26

 

27

Ventura Basin

?

 

1

 

3

Total

69

 

72

 

74

 

 

 

 

 

 

NGLs (MBbl/d)

 

 

 

 

 

San Joaquin Basin

9

 

13

 

13

Total

9

 

13

 

13

 

 

 

 

 

 

Natural Gas (MMcf/d)

 

 

 

 

 

San Joaquin Basin

129

 

138

 

144

Los Angeles Basin

8

 

7

 

8

Ventura Basin

?

 

2

 

5

Sacramento Basin

23

 

24

 

24

Total

160

 

171

 

181

 

 

 

 

 

 

Total Production (MBoe/d)

105

 

114

 

117

 

 

 

 

 

 

Note: MBbl/d refers to thousands of barrels per day; MMcf/d refers to millions of cubic feet per day; MBoe/d refers to thousands of barrels of oil equivalent (Boe) per day. Natural gas volumes have been converted to Boe based on the equivalence of energy content of six thousand cubic feet of natural gas to one barrel of oil. Barrels of oil equivalence does not necessarily result in price equivalence.

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Attachment 4

PRICE STATISTICS

 

 

 

 

 

 

1st Quarter

 

4th Quarter

 

1st Quarter

 

2022

 

2021

 

2021

Oil ($ per Bbl)

 

 

 

 

 

Realized price with derivative settlements

$

60.30

 

 

$

61.00

 

 

$

53.73

 

Realized price without derivative settlements

$

96.13

 

 

$

78.99

 

 

$

60.81

 

 

 

 

 

 

 

NGLs ($/Bbl)

$

78.63

 

 

$

67.61

 

 

$

48.77

 

 

 

 

 

 

 

Natural gas ($/Mcf)

$

6.28

 

 

$

5.94

 

 

$

3.29

 

 

 

 

 

 

 

Index Prices

 

 

 

 

 

Brent oil ($/Bbl)

$

97.38

 

 

$

79.80

 

 

$

61.10

 

WTI oil ($/Bbl)

$

94.29

 

 

$

77.19

 

 

$

57.84

 

NYMEX Henry Hub average daily price ($/MMBtu)

$

4.19

 

 

$

5.27

 

 

$

2.72

 

NYMEX Henry Hub average monthly settled price ($/MMBtu)

$

4.95

 

 

$

5.83

 

 

$

2.69

 

 

 

 

 

 

 

Realized Prices as Percentage of Index Prices

 

 

 

 

 

Oil with derivative settlements as a percentage of Brent

 

62

%

 

 

76

%

 

 

88

%

Oil without derivative settlements as a percentage of Brent

 

99

%

 

 

99

%

 

 

100

%

 

 

 

 

 

 

Oil with derivative settlements as a percentage of WTI

 

64

%

 

 

79

%

 

 

93

%

Oil without derivative settlements as a percentage of WTI

 

102

%

 

 

102

%

 

 

105

%

 

 

 

 

 

 

NGLs as a percentage of Brent

 

81

%

 

 

85

%

 

 

80

%

NGLs as a percentage of WTI

 

83

%

 

 

88

%

 

 

84

%

 

 

 

 

 

 

Natural gas as a percentage of NYMEX average daily price

 

150

%

 

 

113

%

 

 

121

%

Natural gas as a percentage of NYMEX average monthly settled price

 

127

%

 

 

102

%

 

 

 

 

 

 

 

 

 

 

Attachment 5

FIRST QUARTER 2022 DRILLING ACTIVITY

 

 

 

 

 

 

 

 

 

 

San Joaquin

 

Los Angeles

 

Ventura

 

Sacramento

 

 

Wells Drilled

Basin

 

Basin

 

Basin

 

Basin

 

Total

 

 

 

 

 

 

 

 

 

 

Development Wells

 

 

 

 

 

 

 

 

 

Primary

3

 

?

 

?

 

?

 

3

Waterflood

21

 

7

 

?

 

?

 

28

Steamflood

11

 

?

 

?

 

?

 

11

Total (1)

35

 

7

 

?

 

?

 

42

 

 

 

 

 

 

 

 

 

 

(1) Includes steam injectors and drilled but uncompleted wells, which are not included in the SEC definition of wells drilled.

 

 

 

 

 

 

 

 

 

Attachment 6

OIL HEDGES AS OF MARCH 31, 2022

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Q2 2022

 

Q3 2022

 

Q4 2022

 

 

1H 2023

 

 

2H 2023

 

 

2024

 

 

 

 

 

 

 

 

 

 

 

 

Sold Calls

 

 

 

 

 

 

 

 

 

 

 

Barrels per day

 

35,343

 

 

34,380

 

 

25,167

 

 

18,078

 

 

11,555

 

 

?

Weighted-average Brent price per barrel

$

60.63

 

$

60.76

 

$

57.82

 

$

58.63

 

$

57.06

 

 

?

 

 

 

 

 

 

 

 

 

 

 

 

Swaps

 

 

 

 

 

 

 

 

 

 

 

Barrels per day

 

10,669

 

 

10,476

 

 

17,263

 

 

11,806

 

 

16,552

 

 

1,492

Weighted-average Brent price per barrel

$

54.12

 

$

53.97

 

$

58.79

 

$

58.04

 

$

62.95

 

$

79.06

 

 

 

 

 

 

 

 

 

 

 

 

Net Purchased Puts 1

 

 

 

 

 

 

 

 

 

 

 

Barrels per day

 

35,343

 

 

34,380

 

 

25,167

 

 

18,078

 

 

11,555

 

 

1,724

Weighted-average Brent price per barrel

$

65.42

 

$

65.02

 

$

64.47

 

$

76.25

 

$

76.25

 

$

75.00

 

 

 

 

 

 

 

 

 

 

 

 

Sold Puts

 

 

 

 

 

 

 

 

 

 

 

Barrels per day

 

?

 

 

4,000

 

 

1,348

 

 

?

 

 

?

 

 

?

Weighted-average Brent price per barrel

 

?

 

$

32.00

 

$

32.00

 

 

?

 

 

?

 

 

?

 

 

 

 

 

 

 

 

 

 

 

 

1 Purchased and sold puts with the same strike price have been netted together.

 

 

 

 

 

Attachment 7

 

 

 

 

 

 

 

2022 Estimated

TOTAL CRC GUIDANCE1

Consolidated

 

CMB

 

E&P, Corporate & Other

Net Total Production (MBoe/d)

94 - 91

 

 

 

94 - 91

Net Oil Production (MBbl/d)

61 - 57

 

 

 

61 - 57

Operating Costs ($ millions)

$680 - $720

 

 

 

$680 - $720

CMB Expenses2 ($ millions)

$45 - $55

 

$45 - $55

 

 

Adjusted General and Administrative Expenses ($ millions)

$165 - $190

 

$10 - $15

 

$155 - $175

Capital ($ millions)

$340 - $385

 

$15 - $25

 

$325 - $360

Adjusted EBITDAX ($ millions)

$860 - $960

 

($55) - ($70)

 

$930 - $1,015

Free Cash Flow ($ millions)

$330 - $410

 

($70) - ($95)

 

$425 - $480

See Attachment 2 for management's disclosure of its use of these non-GAAP measures and how these measures provide useful information to investors about CRC's results of operations and financial condition. CRC has supplemented its non-GAAP measures of consolidated adjusted EBITDAX and consolidated free cash flow with adjusted EBITDAX for its exploration and production and corporate items (Adjusted EBITDAX for E&P, Corporate & Other) and free cash flow from our exploration and production and corporate items (free cash flow from E&P, Corporate & Other) which CRC believes are useful measures for investors to understand the results of its core oil and gas business. CRC defines adjusted EBITDAX for E&P, Corporate & Other as consolidated adjusted EBITDAX less results attributable to its carbon management business (CMB). CRC defines free cash flow from E&P, Corporate & Other as consolidated free cash flow less results attributable to CMB.

 

2022 Estimated

 

Consolidated

 

CMB

 

E&P, Corporate & Other

($ millions)

Low

 

High

 

Low

 

High

 

Low

 

High

 

Net cash provided (used) by operating activities

$

715

 

 

$

750

 

 

$

(70

)

 

$

(55

)

 

$

785

 

 

$

805

 

 

Capital investments

 

(385

)

 

 

(340

)

 

 

(25

)

 

 

(15

)

 

 

(360

)

 

 

(325

)

 

Estimated free cash flow

$

330

 

 

$

410

 

 

$

(95

)

 

$

(70

)

 

$

425

 

 

$

480

 

 

 

2022 Estimated

 

Consolidated

 

CMB

 

E&P, Corporate & Other

($ millions)

Low

 

High

 

Low

 

High

 

Low

 

High

Net income

$

445

 

 

$

495

 

 

$

(70

)

 

$

(55

)

 

$

515

 

 

$

550

 

Interest and debt expense, net

 

50

 

 

 

57

 

 

 

 

 

 

 

50

 

 

 

57

 

Depreciation, depletion and amortization

 

200

 

 

 

220

 

 

 

 

 

 

 

200

 

 

 

220

 

Exploration expense

 

7

 

 

 

9

 

 

 

 

 

 

 

7

 

 

 

9

 

Income taxes

 

211

 

 

 

256

 

 

 

 

 

 

 

211

 

 

 

256

 

Unusual, infrequent and other items

 

 

 

 

 

 

 

 

 

 

 

Non-cash derivative gain

 

(58

)

 

 

(93

)

 

 

 

 

 

 

(58

)

 

 

(93

)

Gain on asset divestitures

 

(54

)

 

 

(54

)

 

 

 

 

 

 

(54

)

 

 

(54

)

Other

 

2

 

 

 

4

 

 

 

 

 

 

 

2

 

 

 

4

 

Other non-cash items

 

 

 

 

 

 

 

 

 

 

 

Accretion expense

 

40

 

 

 

46

 

 

 

 

 

 

 

40

 

 

 

46

 

Stock-based compensation

 

15

 

 

 

18

 

 

 

 

 

 

 

15

 

 

 

18

 

Post-retirement medical and pension

 

2

 

 

 

2

 

 

 

 

 

 

 

2

 

 

 

2

 

Estimated adjusted EBITDAX

$

860

 

 

$

960

 

 

$

(70

)

 

$

(55

)

 

$

930

 

 

$

1,015

 

 

 

 

 

 

 

 

 

 

 

 

 

Net cash provided (used) by operating activities

$

715

 

 

$

750

 

 

$

(70

)

 

$

(55

)

 

$

785

 

 

$

805

 

Cash interest

 

44

 

 

 

54

 

 

 

 

 

 

 

44

 

 

 

54

 

Cash income taxes

 

30

 

 

 

40

 

 

 

 

 

 

 

30

 

 

 

40

 

Exploration expenditures

 

7

 

 

 

9

 

 

 

 

 

 

 

7

 

 

 

9

 

Working capital changes

 

64

 

 

 

107

 

 

 

 

 

 

 

64

 

 

 

107

 

Estimated adjusted EBITDAX

$

860

 

 

$

960

 

 

$

(70

)

 

$

(55

)

 

$

930

 

 

$

1,015

 

 

 

 

 

 

 

 

 

 

 

 

 

 

2022 Estimated

 

Consolidated

 

CMB

 

E&P, Corporate & Other

($ millions)

Low

 

High

 

Low

 

High

 

Low

 

High

General and administrative expenses

$

180

 

 

$

200

 

 

$

10

 

 

$

15

 

 

$

170

 

 

$

185

 

Equity-settled stock-based compensation

 

(15

)

 

 

(10

)

 

 

 

 

 

 

(15

)

 

 

(10

)

Adjusted general and administrative expenses

$

165

 

 

$

190

 

 

$

10

 

 

$

15

 

 

$

155

 

 

$

175

 

 

 

 

 

 

 

 

 

 

 

 

 

1 Current guidance assumes a 2022 Brent price of $98 per barrel of oil, NGL realizations consistent with prior years and a NYMEX gas price of $5.30 per mcf. CRC's share of production under PSC contracts decreases when commodity prices rise and increases when prices fall.

2 CMB Expenses include start-up expenditures.

 


These press releases may also interest you

at 00:52
It has been a rollercoaster couple of years for investors and traders alike - with incredible levels of stimulus resulting in genuine risk taking in financial markets and, of course, multi-decade high inflation. We are all feeling the effects of this...

at 00:00
Together with Tuya Smart , a global IoT development platform service provider, Goodix (603160.SH) has developed a Smart Tag solution that supports Apple's ecology based on the GR551x series Bluetooth Low Energy SoC. Featured with multi-connection,...

at 00:00
Lemonjuice Capital and Solutions announced that the Pinecrest Townhomes timeshare owners will receive an average of $2,800 per timeshare interest Lemonjuice Capital and Solutions announces the sale of the Pinecrest Townhome timeshare resort located...

at 00:00
Saturday, August 20, 2022, at 12pm, the Ohio Chapter of the U.S. Veterans Motorcycle Club (USVMC) will kick off their Annual VetFest Ohio at the Ohio Renaissance Festival Grounds in Waynesville, OH. As part of the festivities, Team Fastraxtm will...

18 aoû 2022
VAVA announced its 720P Video Baby Monitor is available with a little more personality. In addition to white, parents can now purchase the monitor in calming hues of blue, pink, and green to match the backdrop of the child's nursery....

18 aoû 2022
FF Top Holding LLC (with its affiliates, "we" or "FF Top"), a significant stockholder of Faraday Future Intelligent Electric Inc. ("Faraday Future" or the "Company"), announced today that it has filed a preliminary proxy statement (the "Preliminary...



News published on 5 may 2022 at 06:05 and distributed by: