According to Whiting Petroleum’s (WLL) December presentation the company had 4,930 gross drilling locations in the Bakken region.
According to Whiting Petroleum’s (WLL) December presentation, the company had 5,448 gross drilling locations in the Redtail region.
As WLL isn’t generating enough cash flows to pay its debt, chances are that it might have to rely on asset sales to serve its near-term debt maturities.
In 3Q17, Whiting Petroleum’s FCF (free cash flow), or its operating cash flow minus capital expenditure or capex, was -$200 million.
n 3Q17, Whiting Petroleum (WLL) reported CFO (cash flow from operations) of ~$99.3 million, which was ~34.3% lower than its CFO in 3Q16.
Whiting Petroleum (WLL) lowered its 2017 capital expenditure or capex by $150 million.
Whiting Petroleum’s (WLL) net-debt-to-adjusted EBITDA multiple rose steadily until 2Q16. But after a peak in 2Q16, its EBITDA multiple started falling.
Whiting Petroleum’s (WLL) earnings have improved overall since last year. The company’s 3Q17 earnings were higher YoY as well as on a sequential basis.
Whiting Petroleum (WLL) stock has fallen ~52% YTD. In this series, we’ll be looking at various factors that could have affected WLL’s stock fall.
In the last three months, ConocoPhillips’s median target price has increased from $51.50 to $57.00.
In 2017, COP expects to return almost 65% of its operating cash flow to shareholders, exceeding its target by a wide margin.
ConocoPhillips (COP) plans to reduce its debt load to $15.0 billion by the end of 2019.
ConocoPhillips’s (COP) fiscal 2018 capital expenditure guidance of $5.5 billion is higher than the $3.5 billion that it needs to keep its production flat.
ConocoPhillips’s conventional assets produce ~600.0 Mboepd of production.
At $50.00 per barrel of WTI crude oil prices, ConocoPhillips’s (COP) fiscal 2018 capital requirement is ~$3.00 per barrel of oil equivalent of production.
ConocoPhillips’s (COP) lower capital intensity of ~$3.5 billion per year can be attributed to its resource portfolio, which has a competitive, unmitigated decline rate.
COP’s new conventional projects are expected to add ~175.0 Mboepd by 2020.
In November 2017, ConocoPhillips had ~8.0 Bboe of low-cost unconventional reserves, ~4.0 Bboe of low-cost conventional reserves, and ~3.0 Bboe of low-cost LNG and oil sands reserves.
ConocoPhillips’s (COP) 2016 production mix was ~38.0% crude oil, ~12.0% bitumen, ~9.0% natural gas liquids, ~22.0% international natural gas, and ~19.0% North American natural gas.
ConocoPhillips (COP) expects its fiscal 2018 production to reach 1,180–1,220 Mboepd.