Whiting Petroleum Corporation Common Stock (New)

Good morning. My name is Tom, and I will be your conference facilitator today. Welcome to Waiting Petroleum's second quarter 2021 conference call. The call will be limited to 45 minutes, including Q&A. All lines have been placed on mute to prevent any background noise. After the speaker's remarks, there will be a question and answer period. If you would like to ask a question, simply press star then the number one on your telephone keypad. If you would like to withdraw your question, press star, then the number two on your telephone keypad. Please limit yourself to one question and one follow-up. I will now turn the call over to Brandon Day, Whiting's Investor Relations Manager.

Thank you, Tom. Good morning, everyone. This is Brandon Day, Whiting's Investor Relations Manager. Thank you for joining us to discuss Whiting's second quarter results for the period ended June 30th, 2021. With me today is Whiting's CEO, Lynn Peterson. Also available to answer questions during the Q&A session will be our CFO, Jimmy Henderson, and COO, Chip Reimer. Please be advised that our remarks today, including answers to your questions, include forward-looking statements within the meaning of the Private Securities Litigation Reform Act. These forward-looking statements are subject to risk and uncertainties that could cause actual results to be materially different from those currently anticipated. Those include risks relating to commodity prices, competition, technology, environmental and regulatory compliance, midstream availability, and others described in our filings with the Securities and Exchange Commission, which are incorporated by reference. We disclaim any obligation to update these forward-looking statements. In addition, we may provide certain non-GAAP financial information in this call. The relevant definitions and GAAP reconciliations may be found in our earnings release, which can be found on our website in the investor relations section. Following the prepared remarks, time permitting, we'll open the call to your questions. I would like to remind everyone that a replay of this audio webcast will be available via the company's investor relations page on our website. I'd now like to turn the call over to the CEO of Whiting Petroleum, Mr. Lynn Peterson.

Thanks, Brandon. Good morning, everyone, and thank you for joining us today. You can refer to our 10-Q we filed yesterday and our news release for detailed information. To start with, I would like to commend our team for its continuing efforts to execute on the plan that we set out back in December. As our first half of 2021 results demonstrate, we have proven our ability to optimize our asset base and take advantage of a dramatically different economic landscape. We are clearly in a great position with current commodity prices, solid assets, an enviable balance sheet, and a talented team. The impact of these strengths is evident in our financial results, as well as the updated guidance that I'll discuss shortly. When we combine our strong first half results with our expectations for the second half, assuming crude oil price of $60 per barrel, we now expect whiting to generate approximately 700 million in EBITDAX and over 425 million in pre-cash flow in 2021. which is over a 20 percent free cash flow yield at our current equity price. Looking at our financial results for the second quarter of 2021, we had a net loss on a GAAP basis of $62 million or $1.57 per share during the quarter as compared to a loss of $1 million or $0.02 per share for the previous quarter. Adjusting for certain items, but primarily the mark-to-market of hedging instruments, we had adjusted net income of $118 million or $3.01 per share compared to $108 million or $2.79 per share for the previous quarter. Notably, EBITDAX was $176 million compared to $170 million in the previous quarter due to slightly higher production and commodity prices. Our production for the quarter averaged 92.6 thousand barrels of oil equivalent, of which 58 percent was crude oil. This compares to first quarter production of 89.9 thousand barrels of oil equivalent. Our oil production has remained relatively flat quarter over quarter at approximately 53 thousand barrels per day. The slightly higher BOEs are attributable to an increase in ethane recoveries from our third-party midstream providers with the continuation predicated on supporting ethane fundamentals. As such, we have adjusted both our oil and BOE production forecast for the year to be above the previously guided ranges. We now expect our oil to average 50,000 to 53,000 barrels per day and total production to be 88,000 to 92,000 BOE per day. The increase also takes in consideration a slight decrease in fourth quarter BOEs as a result of the transactions we recently announced. On the CapEx side, we spent $58 million during the second quarter to bring nine gross 5.4 net wells on production, and we drilled nine gross 5.6 operated wells. We ended the quarter with 21 gross 15.3 drilled uncompleted wells, and we anticipate exiting the current year with around 30 drilled uncompleted wells. The company currently has a rig running in the Saanich Field, and intends to bring a second rig into our Cassandra Prospect area later this year. Our completion crew was dropped in May, as expected, and we brought them back in the end of July. We plan to keep the completion crew active for most of the remainder of the year with a short break in the fourth quarter. We expect to bring the crew back in December, which should help smooth out our 2022 production profile. As a result, we've tightened our guidance range of CapEx to $240 million to $252 million for the full year, putting it at the high end of our previous estimates. We, like all operators, are seeing some cost increases as oil remains at its current level, and we have tried to adjust our numbers to reflect our expected outcomes. At the same time, our team continues to drive efficiency, which to date have more than offset the cost increases. Lease operating expenses were $64 million or $7.61 per BOE for the second quarter of 2021. We're seeing faster turnaround on maintenance workover days due to better weather and more efficient processes. The benefit of this activity is shown in our production, so we'll continue to keep these workover rigs at work as these barrels are our most effective and cheapest barrels to bring online. Again, we've tightened the range of guidance for LOE to $235 to $245 million, or roughly $7.30 per BOE, putting it at the high end of our previous estimate. General and administrative expenses of $12 million was modestly higher quarter over quarter as work life continued to transition back to normal. Overall, we continue to run less than our expectations, so we brought our guidance for G&A below the low end of the previous range. A big thanks goes to the team for holding these costs down. Lastly, oil differentials in the second quarter were narrower than the lower end of our guidance range, driven largely by the district court's decision to deny the motion for injunction on DAPL operations, along with a subsequent dismissal of this case. With the risk of transportation interruptions inherently stabilized, coupled with the overall basin production levels that remain significantly behind takeaway capacity, oil spot differentials have benefited as a result. Pipeline utilization has started trending downward from the beginning of the year, and we've seen an increase on rail movements, likely reflecting alternative marketing arrangements put in place prior to the DAPA ruling. Recent pipeline capacity additions placed into service in July and August have also bolstered the continued improvement of oil differentials, and as such, we've revised our four-year projections to reflect this. Overall, when we look back at the guidance provided back in December of 2020, we are pleased to see our progress and our ability to stay within the cost structure and still improve productivity. If you think back to that time, we had $40 oil and a possible DAPL shutdown, so there were many variables going into our planning models. Now turning to recent business development activities, as previously announced, Whiting entered into two separate agreements to divest its red-tail assets in Weld County, Colorado, and purchase assets in Montrell County, North Dakota, allowing for a more focused asset portfolio. Net oil production to come from these two transactions is nearly identical, so the net effect was little impact to our oil guidance. The Colorado assets had a higher daily BOE, but the oil cut was significantly below the assets we picked up in North Dakota. The Red Tail assets had not received capital for several years, and there were no plans to add activity, so it made sense to monetize that asset. The assets acquired in the Williston Basin overlap our Saanich Field and expand our top-tier inventory by over 60 locations. It also included five drilled, uncompleted wells. Saanich was one of the early fields developed in the Williston Basin and was drilled with wellbore azimuth that is not common to today's development standards. These early developments resulted in shorter laterals and stranded tracts of land when offset DSUs were operated by different companies. The acquired assets will allow us to maximize lateral length across several DSUs, allow us to develop stranded resources, and eliminate costs for FracProtect as the acreage is developed. We were fortunate that both of these transactions came together in a timely manner, allowing for an attractive trade with little incremental cash considerations. Thanks and congrats to our team and the counterparties on both deals for getting the agreements in place. We look forward to closing both transactions in mid-September. Our debt levels continue to drop quickly, and in spite of the two transactions noted above, where we anticipate drawing something close to $90 million on our revolver, we still anticipate being in a positive cash position at year-end with nothing drawn on our revolver. Turning to ESG, we are committed to reducing our emissions and improving transparency on how we measure and report. We are working with trade groups like AXPC and API on reporting comparability while honoring sustainability frameworks like SASB. We are also working with an established third party to measure and document our emissions. We have stepped up efforts to coordinate discussions between our facility engineering teams, and our midstream partners to identify, plan, and resolve gas capture limitations for future development. Narrowing our focus to just the S, or social part of the SG, I want to compliment our staff for personally contributing money and then assembling school backpacks with supplies for the precious child and their field backpack drive for underprivileged students in the Denver area. These type of efforts demonstrate the impact our company has on the communities in which we live. Finally, let me address our plans for capital allocation. With the results that we expect and the generation of significant pre-cash flow, we are in an enviable position financially. We have had ongoing discussions internally and with our large investors over potential uses of our liquidity. At this point in time, we continue to evaluate options that balance the desire to return capital to shareholders while at the same time expanding and improving our inventory. Our opinion on this decision will continue to evolve as economic and opportunity landscapes dictate. But having only completed the bankruptcy process less than a year ago, we have decided to temporarily defer any decisions on returning capital. We want our return of capital decisions to be sustainable for future periods under a range of economic conditions. With that, I will open this up for questions. Thank you.