Key Highlights:

• A tenth discovery on the Stabroek Block, offshore Guyana, was announced at the Pluma-1 exploration well located approximately 17 miles south of the Turbot-1 well
• Estimate of gross discovered recoverable resources for the Stabroek Block increased to more than 5 billion barrels of oil equivalent (boe); growing resource base further underpins the potential for at least five floating production, storage and offloading vessels (FPSOs) producing more than 750,000 gross barrels of oil per day (bopd) by 2025
• Year-end proved reserves were 1,192 million boe, organic reserve replacement for 2018 was 166 percent at a finding and development cost of approximately $11.80 per boe
• The Corporation purchased $250 million in common stock to complete our previously announced $1.5 billion share repurchase program

Fourth Quarter Financial and Operating Highlights:

• Net loss was $4 million, or $0.05 per common share, compared with a net loss of $2,677 million, or $8.57 per common share, in the prior-year quarter
• Adjusted net loss was $77 million, or $0.31 per common share, compared to an adjusted net loss of $304 million, or $1.01 per common share, in the fourth quarter of last year
• Oil and gas production averaged 267,000 barrels of oil equivalent per day (boepd), excluding Libya; Bakken net production was 126,000 boepd, up 15 percent from 110,000 boepd in the year ago quarter
• E&P capital and exploratory expenditures were $618 million in the quarter, compared to $568 million in the prior-year quarter
• Cash and cash equivalents, excluding Midstream, were $2.6 billion at December 31, 2018 

2019 Guidance:

• E&P capital and exploratory expenditures are expected to be $2.9 billion
• Oil and gas production, excluding Libya is forecast to be in the range of 270,000 to 280,000 boepd, compared to full year 2018 net production, excluding Libya and assets sold, of 248,000 boepd

Hess Corporation has reported a net loss of $4 million, or $0.05 per common share, in the fourth quarter of 2018, compared to a net loss of $2,677 million, or $8.57 per common share, in the fourth quarter of 2017. On an adjusted basis, the Corporation reported a net loss of $77 million, or $0.31 per common share, in the fourth quarter of 2018, compared with an adjusted net loss of $304 million, or $1.01 per common share, in the prior-year quarter. Fourth quarter 2018 results benefitted from higher U.S. crude oil production, reduced operating costs, and lower depreciation, depletion and amortization expense, compared with the prior-year quarter.

“Our company enters 2019 with a great deal of momentum,” Chief Executive Officer John Hess said. “With our strong execution in 2018, our portfolio is well positioned to deliver approximately 20 percent compound annual cash flow growth and more than 10 percent compound annual production growth through 2025, with a portfolio breakeven of less than $40 per barrel Brent by 2025.”

Exploration & Production

Exploration and Production (E&P) net loss was $5 million in the fourth quarter of 2018, compared to a net loss of $2,592 million, or a net loss of $219 million on an adjusted basis, in the fourth quarter of 2017. The Corporation’s average realized crude oil selling price, excluding the effect of hedging, was $58.11 per barrel in the fourth quarter of 2018, versus $57.32 per barrel in the year-ago quarter. Noncash losses on crude oil hedging contracts reduced fourth quarter 2018 after-tax results by $48 million, compared to a $54 million reduction in the fourth quarter of 2017. The average realized natural gas liquids selling price in the fourth quarter of 2018 was $21.19 per barrel, versus $22.78 per barrel in the prior-year quarter, while the average realized natural gas selling price was $4.82 per mcf, compared to $3.69 per mcf in the fourth quarter of 2017.

Net production, excluding Libya, was 267,000 boepd in the fourth quarter of 2018, down from 282,000 boepd in the prior-year quarter, which included 58,000 boepd from divested assets. Growth in 2018 production was driven by the Bakken and the Gulf of Mexico. Libya net production was 22,000 boepd in the fourth quarter of 2018, compared with 18,000 boepd in the year-ago quarter.

Cash operating costs, which include operating costs and expenses, production and severance taxes, and E&P general and administrative expenses, were $12.60 per boe in the fourth quarter, down 14 percent from $14.58 per boe in the prior-year quarter. This improvement is due to higher production from lower cost Gulf of Mexico assets and cost reduction initiatives. The E&P effective tax rate, excluding items affecting comparability of earnings between periods and Libya, was a benefit of 57 percent in the fourth quarter of 2018, compared to an expense of 21 percent in the prior-year period.

Oil and Gas Reserve Estimates:

Oil and gas proved reserves at December 31, 2018, which are subject to final review, were 1,192 million boe, compared with 1,154 million boe at December 31, 2017. Proved reserve additions and revisions in 2018 were 172 million boe, and primarily related to the Bakken. Additions resulting from asset acquisitions totaled 4 million boe, while asset sales reduced proved reserves by 35 million boe. Excluding asset sales, the Corporation replaced 170 percent of its 2018 production at a finding, development and acquisition cost of approximately $11.75 per boe, which resulted in a year-end 2018 reserve life of 11.5 years.

Operational Highlights for the Fourth Quarter of 2018:

Bakken (Onshore U.S.): Net production from the Bakken increased 15 percent to 126,000 boepd from 110,000 boepd in the year-ago quarter, due to increased drilling activity and improved well performance. The Corporation operated an average of six rigs in the fourth quarter, drilling 36 wells and bringing 35 new wells online.

Gulf of Mexico (Offshore U.S.): Net production from the Gulf of Mexico was 68,000 boepd, compared to 40,000 boepd in the prior-year quarter, primarily reflecting higher production from the Penn State and Conger fields which were impacted by the shutdown of the third-party operated Enchilada platform in the year-ago quarter, and the Stampede Field which commenced production in 2018.

Guyana (Offshore): At the Stabroek Block (Hess - 30 percent), the operator, Esso Exploration and Production Guyana Limited, announced a tenth discovery, the Pluma-1 exploration well which encountered approximately 121 feet of high-quality, hydrocarbon-bearing sandstone reservoir and is located approximately 17 miles south of the Turbot-1 well. As a result of this new discovery and further evaluation of previous discoveries, the estimate of gross discovered recoverable resources for the Stabroek Block was increased to more than 5 billion boe, which further reinforces the potential for at least five FPSOs producing over 750,000 gross bopd by 2025.

Earlier this month the Stena Carron drillship began drilling the Haimara-1 well, located 19 miles east of the Pluma-1 discovery in the southeastern part of the Stabroek Block, and the Noble Tom Madden drillship began drilling the Tilapia-1 prospect, located approximately 3 miles west of the Longtail-1 discovery, in the Turbot area.

Development activities are progressing as follows:

Liza Phase 1: The operator has moved into its peak execution phase ahead of the expected startup in early 2020. Liza Phase 1 will use the Liza Destiny FPSO to produce up to 120,000 gross bopd. Drilling of development wells in the Liza Field is continuing using the Noble Bob Douglas drillship, subsea equipment is being prepared for installation, and the topside facilities modules are being installed on the Liza Destiny FPSO in Singapore, which is expected to arrive offshore Guyana in the third quarter of 2019. Preparations are also underway for the installation of subsea umbilicals, risers and flowlines at the Liza Field in the spring.

Liza Phases 2 and 3: Phase 2 of the Liza development, which will use a second FPSO designed to produce up to 220,000 gross bopd, is expected to be producing by mid-2022. Pending government and regulatory approvals, project sanction is expected in the first quarter of 2019. Development of the Payara Field is expected to be sanctioned in 2019 with first production expected to start up as early as 2023.

Canada (Offshore): In Nova Scotia (Hess - 50 percent), the operator, BP Canada, completed drilling of the Aspy exploration well. The well did not encounter commercial quantities of hydrocarbons. Well costs of $26 million were incurred and expensed in the fourth quarter. The operator is evaluating the data from the Aspy well and determining next steps.

Capital and Exploratory Expenditures:

E&P capital and exploratory expenditures were $618 million in the fourth quarter of 2018, compared to $568 million in the prior-year quarter, reflecting increased drilling in the Bakken, greater development activity in Guyana, and higher exploration spend, partially offset by reduced development spend in the Gulf of Mexico and the impact of 2017 asset sales.

Midstream capital expenditures were $67 million in the fourth quarter of 2018, up from $46 million in the year-ago quarter primarily due to expansion of gathering systems and compression capacity to support Hess and third-party production growth.

Liquidity:

Excluding the Midstream segment, the Corporation had cash and cash equivalents of $2.6 billion and total debt of $5.7 billion at December 31, 2018. The Midstream segment had cash and cash equivalents of $109 million and total debt of $981 million at December 31, 2018. The Corporation’s debt to capitalization ratio was 38.0 percent at December 31, 2018 and 36.1 percent at December 31, 2017.

Net cash provided by operating activities was $881 million in the fourth quarter of 2018, up from $343 million in the fourth quarter of 2017. Net cash provided by operating activities before changes in working capital was $584 million in the fourth quarter of 2018 compared with $492 million in the year-ago quarter. Changes in working capital during the fourth quarter of 2018 was a net inflow of $297 million due to an increase in accounts payable and a reduction in accounts receivable.

In the fourth quarter of 2018, the Corporation purchased a total of $250 million of common shares to complete its previously announced $1.5 billion share repurchase program.