Business Development and New Ventures

Execution risk may be too great for smaller E&Ps vulnerable to cost escalation and now-likely candidates for sales or mergers. Read the full release to learn more.

US onshore shale players have ramped up 2018-19 capital spending intentions and production targets across the board, from the smallest independents to the Global International Oil Companies. Read the full blog post to understand what this means for the unconventional asset space.

Onshore North America continues to be very important to the global supply. The near term forecast seems robust, but the longer term strengths and vulnerabilities of onshore North America plays are less clear. IHS Markit Expert Jerry Kepes discusses the longevity of the onshore North America shale play.

This report, utilizing IHS Markit fixed-income data, dispels the notion that serious debt issues are broad based.

Register for a webinar where IHS Markit experts dissect the STACK, examining critical trends, company positions, infrastructure, productivity drivers and emerging areas.

North American E&P activity growth is expected to level off as we approach the end of the year and move into 2018. How will that impact upstream costs and the oilfield services supply chain? View this on-demand webinar to find.

Frac water demand in the Eagle Ford has plummeted since 2014 due to a drop in completions activity. This presentation outlines our analysis.

Delayed infrastructure expansions in the Appalachia have curtailed 2017 gas production growth. Read the whitepaper showing our updated forecast with the delay in the pipeline expansions, including the Nexus and Rover pipelines.

IHS Markit expects production to remain steady through 2020. Download our presentation to find out more.

Expansion is the trend in the STACK, with Kingfisher County at the center of the Oklahoma unconventional STACK story… for now.

Activity in the Bakken is more sensitive to oil price, given the higher break-even costs compared with other plays such as Permian and Eagle Ford.

North American onshore was decidedly the topic du jour at CERAWeek 2017. Virtually every conversation referenced the role that unconventionals are playing both at a local, national, and global level.

The Permian basin is the most dynamic play in North America today and the Wolfcamp Delaware and Wolfcamp Midland aren't far behind. Read the full whitepaper to see what IHS Markit expects out of this region in the years to come.

Investors are happy to know operators deliver returns in basins other than the Permian as oil settles into the mid $50/bbl range, a difficult feat just two years ago.

The Wolfcamp Formation within the Permian basin and each of its shale benchmarks provides an excellent example of how we can use petrophysical data to gain insight into where an asset holds its current value and how much potential it may have for future further development.

November heating loads to resurrect sinking Mid-Continent demand.

The IHS Markit energy team anticipates that U.S. crude production will rise by over 500,000 barrels per day in 2017 with the Permian Basin supporting the entire production growth wedge.

IHS Markit expects that the sufficient number of private operators remaining means that the Permian M&A frenzy has only just begun, despite relatively high headline acreage valuations.

Permian-focused E&Ps have hedged 65 percent of oil production at more than $50 per barrel. Read the full release to learn more.

The Permian has been and continues to be a hot topic. Read this presentation for a deeper understanding of what to expect from the basin in the second half of 2017 and beyond.

Assigning benches in the Permian is no easy feat. Performance Evaluator from IHS Markit is providing colleagues and clients a way to ask and answer a completely new set of questions about Permian benches and to compare and contrast the performance of operators and areas with much deeper insight.

Rising CAPEX costs tighten economics in hot Permian Basin. Read the full release to learn more.

With natural gas production set to grow rapidly, and pricing differentials already beginning to reflect increasing use of exit capacity, producers face a common dilemma – when will pipeline constraints develop and begin to materially affect netbacks, and what are the best destination markets for new capacity?