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Hess Reports Estimated Results for the Third Quarter of 2018


HESS REPORTS ESTIMATED RESULTS FOR THE THIRD QUARTER OF 2018

Key Highlights:

  • Announced a ninth oil discovery on the Stabroek Block, offshore Guyana, at the Hammerhead-1 exploration well located approximately 13 miles southwest of the Liza-1 well

  • The Hammerhead discovery adds to the previously announced estimate of gross discovered recoverable resources on the Stabroek Block of more than 4 billion barrels of oil equivalent

  • Completed the sale of our joint venture interests in the Utica shale play in eastern Ohio for net proceeds of approximately $400 million

  • Completed the purchase of $250 million in common stock, as part of our previously announced $1.5 billion share repurchase program, bringing total purchases to $1.25 billion; the remaining $250 million is expected to be completed during the fourth quarter

Third Quarter Financial and Operating Highlights:

  • Net income was $52 million, or $0.14 per common share, compared with a net loss of $624 million, or $2.02 per common share, in the prior-year quarter

  • Adjusted net income was $123 million, or $0.38 per common share, compared to an adjusted net loss of $324 million, or $1.07 per common share, in the third quarter of last year

  • Oil and gas production exceeded guidance: total net production averaged 279,000 barrels of oil equivalent per day (boepd), excluding Libya

  • Bakken net production was 118,000 boepd, up from 103,000 boepd in the year-ago quarter

  • Exploration & Production capital and exploratory expenditures were $542 million in the quarter, compared to $558 million in the prior-year quarter

  • Cash and cash equivalents, excluding Midstream, were $2.6 billion at September 30, 2018

NEW YORK, October 31, 2018 — Hess Corporation (NYSE: HES) today reported net income of $52 million, or $0.14 per common share, in the third quarter of 2018, compared to a net loss of $624 million, or $2.02 per common share, in the third quarter of 2017. On an adjusted basis, the Corporation reported net income of $123 million, or $0.38 per common share, in the third quarter of 2018, compared with an adjusted net loss of $324 million, or $1.07 per common share, in the prior-year quarter. Higher realized crude oil selling prices combined with lower operating costs and depreciation, depletion and amortization expense in the third quarter of 2018 more than offset lower production volumes due to asset sales, compared with the prior-year quarter.

“We achieved another strong quarter, delivering higher production and lower costs than ourguidance while keeping capital and exploratory expenditures flat with guidance for the year,” Chief Executive Officer John Hess said. “Our reshaped portfolio is well positioned for a decade plus of capitalefficient production growth with increasing cash generation and returns to shareholders.”

 
 
 

 

 

 

 
 

 

Exploration and Production:

Exploration and Production (E&P) net income in the third quarter of 2018 was $144 million, compared to a net loss of $474 million in the third quarter of 2017. On an adjusted basis, third quarter 2018 net income was $203 million, compared to a net loss of $238 million in the prior-year quarter. TheCorporation's average realized crude oil selling price, including the effect of hedging, was $66.08 perbarrel in the third quarter of 2018, up from $46.97 per barrel in the year-ago quarter. Noncash losses on crude oil hedging contracts reduced third quarter 2018 after-tax results by $49 million. The average realized natural gas liquids selling price in the third quarter of 2018 was $24.29 per barrel, versus $17.22 per barrel in the prior-year quarter, while the average realized natural gas selling price was $4.11 per mcf, compared to $3.35 per mcf in the third quarter of 2017.

Net production, excluding Libya, was 279,000 boepd in the third quarter of 2018, down from 299,000 boepd in the prior-year quarter. Excluding assets sold in 2017 and Libya, third quarter 2017 net production was 249,000 boepd. Growth in production was driven primarily by the Bakken, North Malay Basin and the Gulf of Mexico. Libya net production was 18,000 boepd in the third quarter of 2018, compared with 12,000 boepd in the year-ago quarter. Full year 2018 production, excluding Libya, is now expected to be approximately 255,000 boepd, which is the upper end of our previous guidance range.

Excluding items affecting comparability of earnings between periods and including Libya, cash operating costs, which include operating costs and expenses, production and severance taxes, and E&P general and administrative expenses, were $11.41 per barrel of oil equivalent (boe) in the third quarter, down 17 percent from $13.77 per boe in the prior-year quarter. This improvement is due to increased low-cost production from the Gulf of Mexico and North Malay Basin, cost savings initiatives, and sales of higher cost assets. The E&P effective tax rate, excluding items affecting comparability and Libya, was a benefit of 5 percent in the third quarter of 2018, compared to a benefit of 18 percent in the prior-year period.

Operational Highlights for the Third Quarter of 2018:

Bakken (Onshore U.S.): Net production from the Bakken increased 15 percent to 118,000 boepd from 103,000 boepd in the year-ago quarter due to increased drilling activity, improved well performance, and the impact of severe weather in the third quarter of 2017. The Corporation operated an average of five rigs in the third quarter, drilling 34 wells and bringing 29 new wells online. The Corporation added a sixth rig late in the third quarter of this year. Full year 2018 production guidance for the Bakken remains 115,000 boepd to 120,000 boepd.

Gulf of Mexico (Offshore U.S.): Net production from the Gulf of Mexico was 71,000 boepd, compared to 59,000 boepd in the prior-year quarter, reflecting higher production primarily from the Penn State and Stampede fields. Production from the Conger Field resumed in mid-July after being shut-in since the fourth quarter of 2017 due to a shutdown of the third-party operated Enchilada platform.

North Malay Basin (Offshore Malaysia): Net production from North Malay Basin (Hess operated - 50 percent) was 31,000 boepd, compared to 14,000 boepd in the prior-year quarter. Production from the full field development commenced in July 2017. In July, we entered into a sale and lease-back arrangement for a floating, storage and offloading vessel (FSO) to handle produced condensate from the field and received net proceeds of approximately $130 million.

Guyana (Offshore): At the Stabroek Block (Hess - 30 percent), the operator, Esso Exploration and Production Guyana Limited, announced a ninth discovery on the Block at the Hammerhead-1 exploration well, which encountered approximately 197 feet of high-quality, oil-bearing sandstone reservoir. The well, located approximately 13 miles southwest of the Liza-1 well, targeted Miocene aged reservoir and proves a new play concept for potential development on the Block. The Hammerhead discovery adds to the eight previous discoveries that are estimated to contain gross recoverable resources of more than 4 billion boe and have established the potential for up to five floating, production, storage and offloading (FPSO) vessels producing over 750,000 gross barrels of oil per day (bopd) by 2025.

The Liza Phase 1 development, which is expected to begin producing oil by early 2020, will use the Liza Destiny FPSO to produce up to 120,000 gross bopd. Construction of the FPSO and subsea equipment is well advanced. 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. A third phase of development at the Payara Field is expected to use an FPSO designed to produce approximately 180,000 gross bopd, with first production expected as early as 2023.

A second exploration vessel, the Noble Tom Madden, will commence drilling at the Pluma prospect, which is located approximately 17 miles south of the Turbot discovery, in November.

Canada (Offshore): In Nova Scotia (Hess – 50 percent), drilling of the Aspy exploration well, which is operated by BP Canada, is ongoing.

Suriname (Offshore): At Block 42 (Hess – 33 percent), the operator, Kosmos Energy Ltd, completed drilling operations on the Pontoenoe-1 exploration well in October. High-quality reservoir was encountered, but commercial hydrocarbons were not discovered. Well costs incurred through September 30, 2018 of $25 million were expensed in the third quarter. Well results will be integrated in the ongoing evaluation to inform future exploration on the block.

Midstream:

The Midstream segment, comprised primarily of Hess Infrastructure Partners LP, our 50/50 midstream joint venture, had net income of $30 million in the third quarter of 2018, compared to a net loss of $12 million in the prior-year quarter. Excluding items affecting comparability of earnings between periods, third quarter 2017 net income was $22 million. Third quarter 2017 results attributable to Hess Corporation included an after-tax charge of $34 million related to the sale of Permian Midstream assets that were wholly-owned by Hess Corporation.

Corporate, Interest and Other:

Net results for Corporate, Interest and Other were an after-tax expense of $122 million in the third quarter of 2018, compared to an after-tax expense of $138 million in the third quarter of 2017. On an adjusted basis, third quarter 2018 after-tax expenses were $110 million, compared to $108 million in the third quarter of 2017. Adjusted corporate expenses of $26 million in the third quarter of 2018 were down $10 million, compared to the year-ago quarter primarily as a result of lower employee related costs. In the third quarter of 2018, interest expense of $84 million was $12 million higher than the year- ago quarter primarily due to lower capitalized interest.

Capital and Exploratory Expenditures:

E&P capital and exploratory expenditures were $542 million in the third quarter of 2018, compared to $558 million in the prior-year quarter. The 2018 activity primarily reflects ongoing drilling in the Bakken, increased Liza Phase 1 development activity, exploration wells in Canada and Suriname, and lower expenditures in the Gulf of Mexico. For full year 2018, our E&P capital and exploratory expenditures guidance remains unchanged at approximately $2.1 billion.

Midstream capital expenditures were $83 million in the third quarter of 2018, up from $27 million in the year-ago quarter primarily due to expansion of gathering systems and compression capacity to support Hess and third-party production growth. In addition, Midstream investments in its 50/50 joint venture with Targa Resources were $26 million in the third quarter of 2018.

Liquidity:

Net cash provided by operating activities was $423 million in the third quarter of 2018, up from $88 million in the third quarter of 2017. Net cash provided by operating activities before changes in working capital was $681 million in the third quarter of 2018, which includes a charge to general and administrative expense of $57 million for vacated office space, compared with $428 million in the year- ago quarter. The third quarter 2018 reduction in cash flow from operating activities resulting from changes in working capital was $258 million, which includes premiums paid on calendar 2019 crude oil hedging contracts of $105 million and payment of previously accrued legal claims of $84 million related to former downstream interests.

In the third quarter of 2018, the Corporation purchased a total of $250 million of common shares, bringing total share repurchases under the Corporation's previously announced $1.5 billion repurchaseprogram to $1.25 billion. The remaining $250 million is expected to be purchased during the fourth quarter. In the third quarter, the Corporation also completed the sale of our joint venture interests in the Utica shale play for net cash consideration of approximately $400 million.

Excluding the Midstream segment, the Corporation had cash and cash equivalents of $2.6 billion and total debt of $5.7 billion at September 30, 2018. The Corporation's debt to capitalization ratio was37.5 percent at September 30, 2018 and 36.1 percent at December 31, 2017.

The Midstream segment had cash and cash equivalents of $395 million and total debt of $983 million at September 30, 2018.

 

 

Third Quarter 2018: E&P results include a pre-tax charge of $73 million ($73 million after-tax) in connection with vacated office space, of which $57 million is included in General and administrative expenses and $16 million is included in Depreciation, depletion and amortization. In addition, E&P results include a pre-tax gain of $14 million ($14 million after-tax) from the sale of our joint venture interests in the Utica shale play. As required under accounting standards, Corporate, Interest and Other results include an allocation of noncash income tax expense of $12 million to offset the recognition of a noncash income tax benefit recorded in other comprehensive income resulting from changes in fair value of our 2019 crude oil hedging program.

Third Quarter 2017: Results included an after-tax gain attributable to Hess Corporation of $280 million associated with the sale of our enhanced oil recovery assets in the Permian Basin. This transaction, which included upstream and midstream assets, was allocated to the E&P segment ($314 million after-tax gain) and to the Midstream segment ($34 million after-tax loss). E&P results also included a noncash after-tax charge of $550 million to impair the carrying value of our former assets in Norway. Corporate, Interest and Other results included an after-tax charge of $30 million in connection with vacated office space.

 
 

 



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