Chord Energy Corp 10-K

Item 1A. Risk Factors Our business involves a high degree of risk. If any of the following risks, or any risk described elsewhere in this Annual Report on Form 10-K, actually occurs, our business, financial condition, results of operations or cash flows could suffer. The risks described below are not the only ones facing us. Additional risks not presently known to us or which we currently consider immaterial also may adversely affect us. Risks related to our emergence from bankruptcy We recently emerged from bankruptcy, which may adversely affect our business and relationships. It is possible that our having filed for bankruptcy and our recent emergence from the Chapter 11 Cases may adversely affect our business and relationships with customers, vendors, contractors, employees or suppliers. Due to uncertainties, many risks exist, including the following: • key suppliers, vendors or other contract counterparties may terminate their relationships with us, require additional financial assurances or enhanced performance from us or pursue unreasonable fee increases for their goods or services; • our ability to renew existing contracts and compete for new business may be adversely affected; • our ability to attract, motivate and/or retain key employees and executives may be adversely affected; • landowners may not be willing to lease acreage to us; and • competitors may take business away from us, and our ability to attract and retain customers may be negatively impacted. The occurrence of one or more of these events could have a material and adverse effect on our operations, financial condition and reputation. We cannot assure you that having been subject to bankruptcy protection will not adversely affect our operations in the future. Our actual financial results after emergence from bankruptcy may not be comparable to our historical financial information as a result of the implementation of the Plan and the transactions contemplated thereby and our adoption of fresh start accounting. In connection with the disclosure statement we filed with the Bankruptcy Court, and the hearing to consider confirmation of the Plan, we prepared projected financial information to demonstrate to the Bankruptcy Court the feasibility of the Plan and our ability to continue operations upon our emergence from bankruptcy. Those projections were prepared solely for the purpose of the bankruptcy proceedings and have not been, and will not be, updated on an ongoing basis and should not be relied upon by investors. At the time they were prepared, the projections reflected numerous assumptions concerning our anticipated future performance and with respect to prevailing and anticipated market and economic conditions that were and remain beyond our control and that may not materialize. Projections are inherently subject to substantial and numerous uncertainties and to a wide variety of significant business, economic and competitive risks and the assumptions underlying the projections and/or valuation estimates may prove to be wrong in material respects. Actual results will likely vary significantly from those contemplated by the projections. As a result, investors should not rely on these projections. In addition, our capital structure was significantly altered by the Plan, and we adopted fresh start accounting upon our emergence from bankruptcy. Under fresh start accounting, our assets and liabilities were recorded at fair value as of the Emergence Date. Accordingly, our future financial conditions and results of operations may not be comparable to the financial condition or results of operations reflected in our historical financial statements. Upon our emergence from bankruptcy, the composition of our Board of Directors changed significantly. Pursuant to the Plan, the composition of our Board of Directors changed significantly. Our Board of Directors currently consists of six directors, none of whom served on the Board of Directors prior to our emergence from the Chapter 11 Cases. The new directors have different backgrounds, experiences and perspectives from those individuals who previously served on our Board of Directors and, thus, may have different views on the issues that will determine our future. As a result, our future strategy and plans may differ materially from those of the past. The ability to attract and retain key personnel is critical to the success of our business and may be affected by our emergence from bankruptcy. The success of our business depends on key personnel. The ability to attract and retain these key personnel may be difficult in light of our emergence from bankruptcy, the uncertainties currently facing the business and changes we may make to the organizational structure to adjust to changing circumstances. We may need to enter into retention or other arrangements that 32 T able of Contents could be costly to maintain. If executives, managers or other key personnel resign, retire or are terminated, or their service is otherwise interrupted, we may not be able to replace them in a timely manner and we could experience significant declines in productivity, which could adversely affect our business and results of operations. Risks related to the oil and gas industry and our business Events outside of our control, including a pandemic, epidemic or outbreak of an infectious disease, such as the COVID-19 pandemic, have materially adversely affected, and may further materially adversely affect, our business. We face risks related to pandemics, epidemics, outbreaks or other public health events that are outside of our control, and could significantly disrupt our operations and adversely affect our business and financial condition. For example, the recent global outbreak of COVID-19 has reduced demand for crude oil and natural gas because of significantly reduced global and national economic activity. On March 13, 2020, the United States declared the COVID-19 pandemic a national emergency, and several states, including Texas, North Dakota and Montana, and municipalities have declared public health emergencies. Along with these declarations, there have been extraordinary and wide-ranging actions taken by international, federal, state and local public health and governmental authorities to contain and combat the outbreak and spread of COVID-19 in regions across the United States and the world, including mandates for many individuals to substantially restrict daily activities and for many businesses to curtail or cease normal operations. To the extent COVID-19 continues or worsens, governments may impose additional similar restrictions. In addition, the impact of COVID-19 or other public health events may adversely affect our operations or the health of our workforce and the workforces of our customers and service providers by rendering employees or contractors unable to work or unable to access our and their facilities for an indefinite period of time. There can be no assurance that our personnel will not be impacted by these pandemic diseases or ultimately lead to a reduction in our workforce productivity or increased medical costs or insurance premiums as a result of these health risks. Further, the technology required for the corresponding transition to remote work increases our vulnerability to cybersecurity threats, including threats to gain unauthorized access to sensitive information or to render data or systems unusable, the impact of which may have material adverse effects on our business and operations. See “General risk factors—A cyber incident could result in information theft, data corruption, operational disruption and/or financial loss” below. As the potential impact from COVID-19 is uncertain due to the ongoing and dynamic nature of the circumstances, it is difficult to predict the extent to which it may negatively affect our business, including, without limitation, our operating results, financial position and liquidity, the duration of any potential disruption of our business, how and the degree to which the pandemic may impact our customers, supply chain and distribution network, the health of our employees, the productivity and sustainability of our workforce, our insurance premiums, costs attributable to our emergency measures, payments from customers and uncollectible accounts, limitations on travel, the availability of industry experts and qualified personnel and the market for our securities. Any potential impact will depend on future developments and new information that may emerge regarding the severity and duration of COVID-19, the actions taken by authorities to contain it or treat its impact, and the availability and acceptance of vaccines, all of which are beyond our control. These potential impacts, while uncertain, could continue to adversely affect global economies and financial markets and result in a persistent economic downturn that could continue to have an adverse effect on the industries in which we and our customers operate and on the demand for our products, our operating results and our future prospects. The factors described above have had, and are expected to continue to have, an adverse effect on our business, operating results, financial position and liquidity, which led to us filing the Chapter 11 Cases. We cannot predict when the continuing adverse effect on us will end, and depending on the duration of the pandemic and its severity, this adverse effect could worsen. A substantial or extended decline in commodity prices, for crude oil and, to a lesser extent, natural gas and NGLs, may adversely affect our business, financial condition or results of operations and our ability to meet our capital expenditure obligations and financial commitments. The prices we receive for our crude oil and, to a lesser extent, natural gas and NGLs, heavily influence our revenue, profitability, cash flow from operations, access to capital and future rate of growth. Crude oil, natural gas and NGLs are commodities and, therefore, their prices are subject to wide fluctuations in response to relatively minor changes in supply and demand. Historically, the markets for crude oil, natural gas and NGLs have been volatile, and continue to be volatile. These markets will likely continue to be volatile in the future. The prices we receive for our production, and the levels of our production, depend on numerous factors beyond our control. These factors include the following: • worldwide and regional economic conditions impacting the global supply and demand for crude oil, natural gas and NGLs; • the actions of the Organization of Petroleum Exporting Countries (“OPEC”) and other non-OPEC oil-producing countries, including Russia; 33 T able of Contents • the price and quantity of imports of foreign crude oil, natural gas and NGLs; • political conditions in or affecting other crude oil, natural gas and NGL producing countries, including the current conflicts in and among the Middle East and conditions in South America, China, India and Russia; • the level of global exploration and production; • the level of global crude oil, natural gas and NGL inventories; • events that impact global market demand, including impacts from global health epidemics and concerns, such as the COVID-19 pandemic, which has reduced and may continue to reduce demand for crude oil, natural gas and NGLs because of reduced economic activity; • localized supply and demand fundamentals and regional, domestic and international transportation availability; • weather conditions and natural disasters; • domestic and foreign governmental regulations and policies, including environmental requirements; • speculation as to future commodity prices and the speculative trading of crude oil and natural gas futures contracts; • stockholder activism or activities by non-governmental organizations to limit certain sources of funding for the energy sector or restrict the exploration, development and production of crude oil, natural gas and NGLs and related infrastructure; • price and availability of competitors’ supplies of crude oil, natural gas and NGLs; • technological advances affecting energy consumption; and • the price and availability of alternative fuels. Commodity prices have been volatile in recent years. During 2020, the daily spot prices for NYMEX West Texas Intermediate crude oil (“NYMEX WTI”) ranged from a high of $63.27 per barrel to a low of $(36.98) per barrel, and the daily spot prices for NYMEX Henry Hub natural gas ranged from a high of $3.14 per MMBtu to a low of $1.33 per MMBtu. The significant decline in crude oil prices in early 2020 was largely attributable to the actions of Saudi Arabia and Russia, which resulted in substantial increases in the global supply of crude oil. Specifically, in March 2020, Saudi Arabia and Russia failed to agree on a plan to extend production cuts that expired on April 1, 2020 within OPEC and other non-OPEC, oil-producing countries, including Russia. Subsequently, Saudi Arabia announced plans to increase production to record levels and to reduce the prices at which they sell crude oil. These events, combined with the continued global outbreak of COVID-19, which has significantly impacted both crude oil prices and natural gas prices due to substantially reduced demand for crude oil and natural gas because of reduced global and national economic activity, contributed to a sharp drop in prices for crude oil in early 2020. The impact has not been as severe on natural gas prices, but such prices are susceptible to global actions impacting supply and demand. In April 2020, OPEC announced an agreement among OPEC and other non-OPEC countries, including Russia, to reduce aggregate global production by approximately 10 million barrels a day in May and June of 2020, with gradually decreasing reductions in daily production through the end of 2020. While these cuts in production may offset some of the oversupply of the global crude oil market, crude oil prices have remained low and we cannot predict future impacts to crude oil production and global economic activities. Substantially all of our crude oil and natural gas production is sold to purchasers under short-term (less than 12-month) contracts at market-based prices, and our NGL production is sold to purchasers under long-term (more than 12-month) contracts at market-based prices. Low crude oil, natural gas and NGL prices will reduce our cash flows, borrowing ability, the present value of our reserves and our ability to develop future reserves. See “Risks related to our financial position—Our exploration, development and exploitation projects require substantial capital expenditures. We may be unable to obtain needed capital or financing on satisfactory terms, which could lead to expiration of our leases or a decline in our estimated net crude oil and natural gas reserves.” below. Low crude oil, natural gas and NGL prices may also reduce the amount of crude oil, natural gas and NGLs that we can produce economically and may affect our proved reserves. See also “Our estimated net proved reserves are based on many assumptions that may turn out to be inaccurate. Any significant inaccuracies in these reserve estimates or underlying assumptions will materially affect the quantities and present value of our reserves” below. Drilling for and producing crude oil and natural gas are high-risk activities with many uncertainties that could adversely affect our business, financial condition or results of operations. We use some of the latest available horizontal drilling and completion techniques, which involve risk and uncertainty in their application. Our future financial condition and results of operations will depend on the success of our exploitation, exploration, development and production activities. Our crude oil and natural gas E&P activities are subject to numerous risks beyond our 34 T able of Contents control, including the risk that drilling will not result in commercially viable crude oil or natural gas production. Our decisions to purchase, explore, develop or otherwise exploit drilling locations or properties will depend in part on the evaluation of data obtained through geophysical and geological analyses, production data and engineering studies, the results of which are often inconclusive or subject to varying interpretations. For a discussion of the uncertainty involved in these processes, see “Our estimated net proved reserves are based on many assumptions that may turn out to be inaccurate. Any significant inaccuracies in these reserve estimates or underlying assumptions will materially affect the quantities and present value of our reserves” below. Our cost of drilling, completing and operating wells is often uncertain before drilling commences. These levels of uncertainty may be increased with respect to our position in the Permian Basin acquired in 2018 due to less experience operating in the area. Overruns in planned expenditures are common risks that can make a particular project uneconomical. Further, many factors may curtail, delay or cancel our scheduled drilling projects, including the following: • shortages of or delays in obtaining equipment and qualified personnel; • facility or equipment malfunctions and/or failure; • unexpected operational events, including accidents; • pressure or irregularities in geological formations; • adverse weather conditions, such as blizzards, ice storms and floods; • reductions in crude oil, natural gas and NGL prices; • delays imposed by or resulting from compliance with regulatory requirements; • proximity to and capacity of transportation facilities; • title problems; and • limitations in the market for crude oil and natural gas. Our operations involve utilizing the latest drilling and completion techniques as developed by us and our service providers in order to maximize cumulative recoveries and therefore generate the highest possible returns. Risks that we face while drilling include, but are not limited to, the following: • spacing of wells to maximize production rates and recoverable reserves; • landing the well bore in the desired drilling zone; • staying in the desired drilling zone while drilling horizontally through the formation; • running the casing the entire length of the well bore; and • the ability to run tools and other equipment consistently through the horizontal well bore. Risks that we face while completing our wells include, but are not limited to, the following: • the ability to fracture stimulate the planned number of stages; • the ability to run tools the entire length of the well bore during completion operations; • the ability to successfully clean out the well bore after completion of the final fracture stimulation stage; and • protecting nearby producing wells from the impact of fracture stimulation. Ultimately, the success of these drilling and completion techniques can only be evaluated over time as more wells are drilled and production profiles are established over a sufficiently long time period. If our drilling results are less than anticipated or we are unable to execute our drilling program because of capital constraints, lease expirations, access to gathering systems and limited takeaway capacity or otherwise, and/or crude oil, natural gas and NGL prices decline, the return on our investment for certain projects may not be as attractive as we anticipate. Further, as a result of any of these developments, we could incur material write-downs of our oil and gas properties and the value of our undeveloped acreage could decline in the future. Our estimated net proved reserves are based on many assumptions that may turn out to be inaccurate. Any significant inaccuracies in these reserve estimates or underlying assumptions will materially affect the quantities and present value of our reserves. The process of estimating crude oil and natural gas reserves is complex. It requires interpretations of available technical data and many assumptions, including assumptions relating to current and future economic conditions and commodity prices. Any significant inaccuracies in these interpretations or assumptions could materially affect the estimated quantities and present value of reserves shown in this Annual Report on Form 10-K. See “Item 1. Business—Exploration and Production Operations” for information about our estimated crude oil and natural gas reserves and the PV-10 and Standardized Measure as of December 31, 2020, 2019 and 2018. 35 T able of Contents In order to prepare our estimates, we must project production rates and the timing of development expenditures. We must also analyze available geological, geophysical, production and engineering data. The extent, quality and reliability of this data can vary. The process also requires economic assumptions about matters such as crude oil and natural gas prices, drilling and operating expenses, capital expenditures, taxes and availability of funds. Although the reserve information contained herein is reviewed by our independent reserve engineers, estimates of crude oil and natural gas reserves are inherently imprecise. Actual future production, crude oil and natural gas prices, revenues, taxes, development expenditures, operating expenses and quantities of recoverable oil and natural gas reserves will vary from our estimates. Any significant variance could materially affect the estimated quantities and present value of reserves shown in this Annual Report on Form 10-K. In addition, we may adjust estimates of net proved reserves to reflect production history, results of exploration and development, prevailing crude oil and natural gas prices and other factors, many of which are beyond our control. Due to the limited production history of our undeveloped acreage, the estimates of future production associated with such properties may be subject to greater variance to actual production than would be the case with properties having a longer production history. You should not assume that the present value of future net revenues from our estimated net proved reserves is the current market value of our estimated net crude oil and natural gas reserves. In accordance with SEC requirements, we based the estimated discounted future net revenues from our estimated net proved reserves on the unweighted arithmetic average of the first-day-of-the-month price for the preceding 12 months without giving effect to derivative transactions. Actual future net revenues from our oil and gas properties will be affected by factors such as: • actual prices we receive for crude oil and natural gas; • actual cost of development and production expenditures; • the amount and timing of actual production; and • changes in governmental regulations or taxation. The timing of both our production and our incurrence of expenses in connection with the development and production of oil and gas properties will affect the timing and amount of actual future net revenues from estimated net proved reserves, and thus their actual present value. In addition, the 10% discount factor we use when calculating discounted future net revenues may not be the most appropriate discount factor based on interest rates in effect from time to time and risks associated with us or the oil and natural industry in general. Actual future prices and costs may differ materially from those used in the present value estimates included in this Annual Report on Form 10-K. Any significant future price changes will have a material effect on the quantity and present value of our estimated net proved reserves. If crude oil, natural gas and NGL prices decline or for an extended period of time remain at depressed levels, we may be required to take write-downs of the carrying values of our oil and gas properties. We review our proved oil and gas properties for impairment whenever events and circumstances indicate that a decline in the recoverability of their carrying value may have occurred. In addition, we assess our unproved properties periodically for impairment on a property-by-property basis based on remaining lease terms, drilling results or future plans to develop acreage. Based on specific market factors and circumstances at the time of prospective impairment reviews, and the continuing evaluation of development plans, production data, economics and other factors, we may be required to write down the carrying value of our oil and gas properties, which may result in a decrease in the amount available under the Oasis Credit Facility. A write-down constitutes a non-cash charge to earnings. During the year ended December 31, 2020, we recognized impairment charges of $4.4 billion on our proved oil and gas properties and $401.1 million on our unproved oil and gas properties. During the years ended December 31, 2019 and 2018, we recognized impairment charges on our unproved oil and gas properties of $5.4 million and $0.9 million, respectively. We also recorded an impairment charge of $383.4 million on oil and gas properties held for sale during the year ended December 31, 2018. If crude oil, natural gas and NGL prices continue to decline or for an extended period of time remain at depressed levels, we may be caused to incur impairment charges in the future, which could have a material adverse effect on our access to capital and our results of operations for the periods in which such charges are taken. The unavailability or high cost of additional drilling rigs, equipment, supplies, personnel and oilfield services or the unavailability of sufficient transportation for our production could adversely affect our ability to execute our exploration and development plans within our budget and on a timely basis. Our industry is cyclical and, from time to time, there is a shortage of drilling rigs, equipment, supplies or qualified personnel. During these periods, the costs of rigs, equipment, supplies and personnel are substantially greater and their availability to us may be limited. Additionally, these services may not be available on commercially reasonable terms. 36 T able of Contents Shortages or the high cost of drilling rigs, equipment, supplies, personnel or oilfield services or the unavailability of sufficient transportation for our production could delay or adversely affect our development and exploration operations or cause us to incur significant expenditures that are not provided for in our capital plan, which could have a material adverse effect on our business, financial condition or results of operations. Additionally, compliance with new or emerging legal requirements that affect midstream operations in North Dakota or Texas may reduce the availability of transportation for our production. For example, the NDIC adopted regulations in late 2013 that impose more rigorous pipeline development standards on midstream operators, some of whom we rely on to construct and operate pipeline infrastructure to transport the crude oil and natural gas we produce. We will not be the operator on all of our drilling locations, and, therefore, we will not be able to control the timing of exploration or development efforts, associated costs, or the rate of production of any non-operated assets. We may enter into arrangements with respect to existing or future drilling locations that result in a greater proportion of our locations being operated by others. As a result, we may have limited ability to exercise influence over the operations of the drilling locations operated by our partners. Dependence on the operator could prevent us from realizing our target returns for those locations. The success and timing of exploration and development activities operated by our partners will depend on a number of factors that will be largely outside of our control, including: • the timing and amount of capital expenditures; • the operator’s expertise and financial resources; • approval of other participants in drilling wells; • selection of technology; and • the rate of production of reserves, if any. This limited ability to exercise control over the operations of some of our drilling locations may cause a material adverse effect on our results of operations and financial condition. All of our producing properties and operations are located in the Williston Basin and the Permian Basin regions, making us vulnerable to risks associated with operating in a limited number of geographic areas. Our producing properties are geographically concentrated in Williston Basin in northwestern North Dakota and northeastern Montana and the Permian Basin in West Texas, with these two basins comprising 86% and 14%, respectively, of our production during the year ended December 31, 2020. As a result, we may be disproportionately exposed to the impact of economics in the Williston Basin and the Permian Basin or delays or interruptions of production from those wells caused by transportation capacity constraints, curtailment of production, availability of equipment, facilities, personnel or services, significant governmental regulation, natural disasters, adverse weather conditions, plant closures for scheduled maintenance or interruption of transportation of crude oil or natural gas produced from the wells in those areas. In addition, the effect of fluctuations on supply and demand may become more pronounced within specific geographic crude oil and natural gas producing areas such as the Williston Basin and the Permian Basin, which may cause these conditions to occur with greater frequency or magnify the effect of these conditions. Our crude oil, natural gas and NGLs are sold in a limited number of geographic markets and each has a generally fixed amount of storage and processing capacity. As a result, if such markets become oversupplied with crude oil, natural gas and/or NGLs, it could have a material negative effect on the prices we receive for our products and therefore an adverse effect on our financial condition and results of operations. Variances in quality may also cause differences in the value received for our products. Due to the concentrated nature of our portfolio of properties, a number of our properties could experience any of the same conditions at the same time, resulting in a relatively greater impact on our results of operations than they might have on other companies that have a more diversified portfolio of properties. The impact of regional economics or delays or interruptions of production in an area could have a material adverse effect on our financial condition and results of operations. The marketability of our production is dependent upon crude oil, natural gas and NGL gathering, processing and transportation facilities, some of which are owned by third parties. Market conditions or operational impediments could hinder our access to crude oil, natural gas or NGL markets, delay our production or reduce the realized prices we receive . Market conditions or the unavailability of satisfactory oil, natural gas and NGL gathering, processing and transportation arrangements may hinder our access to oil, natural gas and NGL markets or delay production from our wells. Our ability to market our production depends in part on the availability, proximity and capacity of gathering systems, pipelines and processing facilities owned by midstream operators, including third parties and OMP. Our failure to obtain such midstream services on acceptable terms could materially harm our business. The shutdown, unavailability of, or lack of, available capacity on these systems and facilities could result in the shut-in of producing wells, the flaring of natural gas that could result in restrictions on production or monetary sanctions, or the delay, or discontinuance of, development plans for properties. The 37 T able of Contents transportation of our production can be interrupted by other customers that have firm arrangements. In addition, these midstream operators may also impose specifications for the products that they are willing to accept. If the total mix of a product fails to meet the applicable product quality specifications, the midstream operators may refuse to accept all or a part of the products or may invoice us for the costs to handle or damages from receiving the out-of-specification products. In those circumstances, we may be required to delay the delivery of or find alternative markets for that product, or shut-in the producing wells that are causing the products to be out of specification, potentially reducing our revenues. The disruption of midstream operators’ facilities due to maintenance, weather or other interruptions of service could also negatively impact our ability to market and deliver our products. We have no control over when or if such facilities are restored. If our production becomes shut-in for any of these or other reasons, we would be unable to realize revenue from those wells until other arrangements were made to deliver the products to market. A total shut-in of our production could materially affect us due to a resulting lack of cash flows, and if a substantial portion of the production is hedged at lower than market prices, those financial hedges would have to be paid from borrowings absent sufficient cash flows. In addition, the impact of pending and future legal proceedings on these systems, pipelines and facilities can affect our ability to market our products and have a negative impact on realized pricing. On July 6, 2020, the operator of the Dakota Access Pipeline (“DAPL”) was ordered by a U.S. District court to halt oil flow and empty the pipeline within 30 days while an environmental impact study (“EIS”) is completed. On July 15, 2020, the U.S. Court of Appeals for the District of Columbia Circuit issued a temporary administrative stay while the court considers the merits of a longer-term emergency stay order through the appeals process. On January 26, 2021, the U.S. Court of Appeals for the District of Columbia Circuit upheld the U.S. District court’s ruling that an EIS is needed and also reaffirmed its earlier decision which allows DAPL to operate through the EIS process. We regularly use DAPL in addition to other outlets to market our crude oil in the Williston Basin to end markets. To mitigate the risks associated with a potential shutdown of DAPL, we have proactively arranged for portions of our Williston Basin crude oil volumes to be sold at alternative outlets at fixed differentials to NYMEX WTI. In the event DAPL were to cease operating, we would anticipate Williston Basin crude oil prices to weaken materially before improving as the market adapts to rail transportation. A portion of our crude oil and NGL production is transported to market centers by rail. Potential crude oil or NGL train derailments or crashes as well as state or federal restrictions on the vapor pressure of crude oil transported by, or loaded on or unloaded from, railcars could also impact our ability to market and deliver our products and cause significant fluctuations in our realized crude oil and natural gas prices due to tighter safety regulations imposed on crude-by-rail transportation and interruptions in service. See “Item 1. Business—Regulation—Regulation of transportation and sales of crude oil” for more information about the regulations relating to the transport of crude oil by rail. The crude oil business environment has historically been characterized by periods when crude oil production has surpassed local transportation and refining capacity, resulting in substantial discounts in the price received for crude oil versus prices quoted for NYMEX WTI crude oil. In the past, there have been periods when this discount has substantially increased due to the production of crude oil in the area increasing to a point that it temporarily surpasses the available pipeline transportation, rail transportation and refining capacity in the area. Expansions of both rail and pipeline facilities have reduced the prior constraint on crude oil transportation out of the Williston Basin and the Permian Basin and improved basin differentials received at the lease. See “Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Commodity Prices” for information about our realized crude oil prices and average price differentials relative to NYMEX WTI for the years ended December 31, 2020, 2019 and 2018. Additionally, the refining capacity in the U.S. Gulf Coast is insufficient to refine all of the light sweet crude oil being produced in the United States. The United States imports heavy crude oil and exports light crude oil to utilize the U.S. Gulf Coast refineries that have more heavy refining capacity. If light sweet crude oil production remains at current levels or continues to increase, demand for our light crude oil production could result in widening price discounts to the world crude oil prices and potential shut-in or reduction of production due to a lack of sufficient markets despite the lift on prior restrictions on the exporting of crude oil and natural gas from the United States. The development of our proved undeveloped reserves may take longer and may require higher levels of capital expenditures than we currently anticipate. Therefore, our undeveloped reserves may not be ultimately developed or produced. Approximately 29% of our estimated net proved reserves were classified as proved undeveloped as of December 31, 2020. Development of these reserves may take longer and require higher levels of capital expenditures than we currently anticipate. The future development of our proved undeveloped reserves is dependent on future commodity prices, costs and economic assumptions that align with our internal forecasts as well as access to liquidity sources, such as capital markets, the Oasis Credit Facility and derivative contracts. Delays in the development of our reserves or increases in costs to drill and develop such reserves will reduce the PV-10 of our estimated proved undeveloped reserves and future net revenues estimated for such reserves and may result in some projects becoming uneconomic. In addition, delays in the development of reserves could cause us to have to reclassify our proved reserves as unproved reserves. 38 T able of Contents Unless we replace our crude oil and natural gas reserves, our reserves and production will decline, which would adversely affect our business, financial condition and results of operations. Unless we conduct successful development, exploitation and exploration activities or acquire properties containing proved reserves, our estimated net proved reserves will decline as those reserves are produced. Producing oil and natural gas reservoirs generally are characterized by declining production rates that vary depending upon reservoir characteristics and other factors. Our future crude oil and natural gas reserves and production, and therefore our cash flows and income, are highly dependent on our success in efficiently developing and exploiting our current reserves and economically finding or acquiring additional recoverable reserves. We may not be able to develop, exploit, find or acquire additional reserves to replace our current and future production at acceptable costs. If we are unable to replace our current and future production, the value of our reserves will decrease, and our business, financial condition and results of operations would be adversely affected. Our business is subject to operating risks that could result in substantial losses or liability claims, and we may not be insured for, or our insurance may be inadequate to protect us against, these risks. We are not insured against all risks. Additionally, certain of our insurance policies also provide coverage to OMP and as a result, a claim by OMP against one of our shared insurance policies may reduce the remaining amount of coverage available to us. Losses and liabilities arising from uninsured and underinsured events could materially and adversely affect our business, financial condition or results of operations. Our E&P activities are subject to all of the operating risks associated with drilling for and producing crude oil and natural gas, including the possibility of: • environmental hazards, such as natural gas leaks, c rude oil and produced water spills, pipeline and tank ruptures, encountering naturally occurring radioactive materials and unauthorized discharges of brine, well stimulation and completion fluids, toxic gas, such as hydrogen sulfide, or other pollutants into the environment; • abnormally pressured formations; • shortages of, or delays in, obtaining water for hydraulic fracturing activities; • mechanical difficulties, such as stuck oilfield drilling and service tools and casing failure; • personal injuries and death; and • natural disasters. Any of these risks could adversely affect our ability to conduct operations or result in substantial losses to us as a result of: • injury or loss of life; • damage to and destruction of property, natural resources and equipment; • pollution and other environmental damage; • regulatory investigations and penalties; • suspension of our operations; and • repair and remediation costs. Insurance against all operational risk is not available to us. We are not fully insured against all risks, including development and completion risks that are generally not recoverable from third parties or insurance. In addition, pollution and environmental risks generally are not fully insurable. Also, we may elect not to obtain insurance if we believe that the cost of available insurance is excessive relative to the risks presented. The occurrence of an event that is not fully covered by insurance could have a material adverse effect on our business, financial condition and results of operations. Drilling locations that we decide to drill may not yield crude oil or natural gas in commercially viable quantities. Our drilling locations are in various stages of evaluation, ranging from a location which is ready to drill to a location that will require substantial additional interpretation. There is no way to predict in advance of drilling and testing whether any particular location will yield crude oil or natural gas in sufficient quantities to recover drilling or completion costs or to be economically viable. The use of technologies and the study of producing fields in the same area will not enable us to know conclusively prior to drilling whether crude oil or natural gas will be present or, if present, whether crude oil or natural gas will be present in sufficient quantities to be economically viable. Even if sufficient amounts of crude oil or natural gas exist, we may damage the potentially productive hydrocarbon bearing formation or experience mechanical difficulties while drilling or completing the well, resulting in a reduction in production from the well or abandonment of the well. If we drill additional wells that we identify as dry holes in our current and future drilling locations, our drilling success rate may decline and materially harm our business. We cannot assure you that the analogies we draw from available data from other wells, more fully explored locations or producing fields will be applicable to our drilling locations. Further, initial production rates reported by us or other operators 39 T able of Contents in the Williston Basin and the Permian Basin may not be indicative of future or long-term production rates. In sum, the cost of drilling, completing and operating any well is often uncertain, and new wells may not be productive. Our potential drilling location inventories are scheduled to be drilled over several years, making them susceptible to uncertainties that could materially alter the occurrence or timing of their drilling. Our management has identified and scheduled drilling locations as an estimation of our future multi-year drilling activities on our existing acreage. These potential drilling locations, including those without proved undeveloped reserves, represent a significant part of our execution strategy. Our ability to drill and develop these locations is subject to a number of uncertainties, including the availability of capital, seasonal conditions, regulatory approvals, crude oil and natural gas prices, costs and drilling results. These levels of uncertainty may be increased with respect to our positions in the Permian Basin acquired in 2018 due to less experience operating in the area. In addition, we may not be able to raise the substantial amount of capital that would be necessary to drill a substantial portion of our potential drilling locations. See also “Risks related to our financial position—Our exploration, development and exploitation projects require substantial capital expenditures. We may be unable to obtain needed capital or financing on satisfactory terms, which could lead to expiration of our leases or a decline in our estimated net crude oil and natural gas reserves.” Because of these uncertainties, we do not know if the numerous potential drilling locations we have identified will ever be drilled or if we will be able to produce crude oil or natural gas from these or any other potential drilling locations. Pursuant to existing SEC rules and guidance, subject to limited exceptions, proved undeveloped reserves may only be booked if they relate to wells scheduled to be drilled within five years of the date of booking. These rules and guidance may limit our potential to book additional proved undeveloped reserves as we pursue our drilling program. Certain of our undeveloped leasehold acreage is subject to leases that will expire over the next several years unless production is established on units containing the acreage, the primary term is extended through continuous drilling provisions or the leases are renewed. Failure to drill sufficient wells in order to hold acreage will result in a substantial lease renewal cost, or if renewal is not feasible, loss of our lease and prospective drilling opportunities . As of December 31, 2020, approximately 98% and 74% of our total net acreage in the Williston Basin and the Permian Basin, respectively, was held by production. The leases for our net acreage not held by production will expire at the end of their primary term unless production is established in paying quantities under the units containing these leases, the leases are held beyond their primary terms under continuous drilling provisions or the leases are renewed. In the Williston Basin, our acreage must be drilled before lease expiration, generally within three to five years, in order to hold the acreage by production. Unless production is established within the spacing units covering the undeveloped acres on which some of the locations are identified, the leases for such acreage will expire. In the Permian Basin, our acreage must be drilled before lease or term assignment expiration and, in some leases, must be further perpetuated via additional drilling activity to satisfy continuous drilling and development provisions, including under the CDA. Additionally, certain leases and term assignments in the Permian Basin require development at various depths in order to perpetuate our ownership as to those depths. If we fail to meet certain drilling and development obligations under the CDA, the CDA may be subject to early termination, in which case, we would lose rights to certain non-productive acreage and depths and may be obligated to pay non-performance fees of up to approximately $100 million. As of December 31, 2020, we had an aggregate of 6,648 net acres expiring in 2021, 1,121 net acres expiring in 2022 and 167 net acres expiring in 2023 in the Williston and Permian Basins. The cost to renew such leases may increase significantly and we may not be able to renew such leases on commercially reasonable terms or at all. In addition, on certain portions of our acreage, third-party leases become immediately effective if our leases expire. Our ability to drill and develop these locations depends on a number of uncertainties, including crude oil and natural gas prices, the availability and cost of capital, drilling and production costs, availability of drilling services and equipment, drilling results, lease expirations, gathering system and pipeline transportation constraints, access to and availability of water sourcing and distribution systems, regulatory approvals and other factors. As such, our actual drilling activities may materially differ from our current expectations, which could adversely affect our business. During the years ended December 31, 2020, 2019 and 2018, the Predecessor recorded non-cash impairment charges of $401.1 million, $5.4 million and $0.9 million, respectively, on our unproved properties due to expiring leases, periodic assessments and drilling plan uncertainty on certain acreage of our unproved properties. Due to the extraordinary market conditions during 2020, we agreed with University Lands to pause operations, and on December 31, 2020, we executed an amendment to the CDA reflecting that agreement. The amendment reduced or postponed certain drilling and development obligations for the year ended December 31, 2020 and did not result in the payment of any penalty. Our current budget contemplates drilling activity which does not meet certain obligations under the CDA. We are currently in discussions with University Lands similar to those held in 2020, in which we will seek an amendment for the reduction of our drilling obligations for 2021 similar to that previously received. We can provide no assurance that we will be successful in obtaining this amendment. Given the early stages of our discussions with University Lands on our drilling obligations for 2021 and the continuous flexibility we have with our drilling program to adjust as market and business conditions warrant, we cannot predict whether we will incur losses or estimate the amount of any potential loss. 40 T able of Contents Our operations are subject to environmental and occupational health and safety laws and regulations that may expose us to significant costs and liabilities. Our crude oil and natural gas E&P operations, midstream operations and related operations are subject to stringent federal, tribal, regional, state and local laws and regulations governing occupational health and safety aspects, the discharge of materials into the environment or otherwise relating to environmental protection. These laws and regulations may impose numerous obligations that are applicable to our operations and services. The trend of more expansive and stringent environmental and occupational health and safety legislation and regulations applied to the oil and gas industry could continue, resulting in material increases in our costs of doing business and consequently affecting profitability. See “Item 1. Business—Regulation—Environmental and occupational health and safety regulation” for more discussion on these environmental and occupational health and safety matters. Compliance with existing environmental and occupational safety and health laws, regulations, executive orders and other regulatory initiatives, or any other such new legal requirements, could, among other things, require us or our customers to install new or modified emission controls on equipment or processes, incur longer permitting timelines, and incur significantly increased capital or operating expenditures, which costs may be significant. One or more of these developments that impact us or our customers could have a material adverse effect on our business, results of operations and financial condition and reduce demand for our midstream services. Failure to comply with federal, state and local laws and regulations could adversely affect our ability to produce, gather and transport our crude oil and natural gas and may result in substantial penalties. Our operations are substantially affected by federal, state and local laws and regulations, particularly as they relate to the regulation of crude oil and natural gas production and transportation. These laws and regulations include regulation of crude oil and natural gas exploration and production and related operations, including a variety of activities related to the drilling of wells, and the interstate transportation of crude oil and natural gas by federal agencies such as FERC, as well as state agencies. We may incur substantial costs in order to maintain compliance with these laws and regulations. Due to recent incidents involving the release of crude oil and natural gas and fluids as a result of drilling activities in the United States, there have been a variety of regulatory initiatives at the federal and state levels to restrict crude oil and natural gas drilling operations in certain locations. Any increased regulation or suspension of crude oil and natural gas exploration and production, or revision or reinterpretation of existing laws and regulations, that arise out of these incidents or otherwise could result in delays and higher operating costs. Such costs or significant delays could have a material adverse effect on our business, financial condition and results of operations. With regard to our physical purchases and sales of energy commodities, we must also comply with anti-market manipulation laws and related regulations enforced by FERC, the CFTC and the FTC. To the lesser extent we are a shipper on interstate pipelines, we must comply with the FERC-approved tariffs of such pipelines and with federal policies related to the use of interstate capacity. Should we fail to comply with all applicable statutes, rules, regulations and orders of FERC, the CFTC or the FTC, we could be subject to substantial penalties and fines. Climate change and climate change legislation and regulatory initiatives could result in increased operating costs, restrictions on drilling and reduced demand for the crude oil and natural gas that we produce. The threat of climate change continues to attract considerable attention in the United States and foreign countries. As a result, numerous proposals have been made and are likely to continue to be made at the international, national, regional and state levels of government to monitor and limit emissions of GHGs as well as to eliminate such future emissions. As a result, our operations as well as the operations of our midstream customers are subject to a series of regulatory, political, litigation and financial risks associated with the production and processing of fossil fuels and emission of GHGs. See “Item 1. Business—Regulation—Environmental and occupational health and safety regulation” for more discussion on the threat of climate change and restriction of GHG emissions. The adoption and implementation of any international, federal, regional or state legislation, executive actions, regulations or other regulatory initiatives that impose more stringent standards for GHG emissions from the oil and natural gas industry or otherwise restrict the areas in which this industry may produce crude oil and natural gas or generate GHG emissions could result in increased compliance costs or costs of consuming fossil fuels. Such legislation, executive actions or regulations could result in increased costs of our or our customers’ compliance or costs of consuming, and thereby reduce demand for crude oil and natural gas, which could reduce demand for our midstream services. Additionally, political, financial and litigation risks may result in us or our customers restricting, delaying or canceling production activities, incurring liability for infrastructure damages as a result of climatic changes, or impairing the ability to continue to operate in an economic manner, which also could reduce demand for our midstream and services. The occurrence of one or more of these developments could have a material adverse effect on our business, financial condition, results of operations and cash flows. Moreover, the increased competitiveness of alternative energy sources (such as wind, solar geothermal, tidal and biofuels) could reduce demand for hydrocarbons, and therefore for our products and services, which would lead to a reduction in our revenues. Increasing attention and federal actions in regards to ESG matters may impact our business. Companies across all industries are facing increasing scrutiny from stakeholders related to their ESG practices. Companies which do not adapt to or comply with investor or stakeholder expectations and standards, which are evolving, or which are 41 T able of Contents perceived to have not responded appropriately to the growing concern for ESG issues, regardless of whether there is a legal requirement to do so, may suffer from reputational damage and the business, financial condition, and/or stock price of such a company could be materially and adversely affected. Increasing attention to climate change, increasing societal expectations on companies to address climate change, and potential consumer use of substitutes to energy commodities may result in increased costs, reduced demand for our hydrocarbon products and midstream services, reduced profits, increased governmental investigations and private litigation against us, and negative impacts on our stock price and access to capital markets. In addition, organizations that provide information to investors on corporate governance and related matters have developed ratings processes for evaluating companies on their approach to ESG matters. Currently, there are no universal standards for such scores or ratings, but the importance of sustainability evaluations is becoming more broadly accepted by investors and shareholders. Such ratings are used by some investors to inform their investment and voting decisions. Additionally, certain investors use these scores to benchmark companies against their peers and if a company is perceived as lagging, these investors may engage with companies to require improved ESG disclosure or performance. Moreover, certain members of the broader investment community may consider a company’s sustainability score as a reputational or other factor in making an investment decision. Consequently, a low sustainability score could result in exclusion of our common stock from consideration by certain investment funds, engagement by investors seeking to improve such scores and a negative perception of us by certain investors. Federal, state and local legislative and regulatory initiatives relating to hydraulic fracturing as well as governmental reviews of such activities could result in increased costs and additional operating restrictions or delays in the completion of crude oil and natural gas wells and adversely affect our production. Hydraulic fracturing is an important and common practice that is used to stimulate production of natural gas and/or crude oil from dense subsurface rock formations. The process involves the injection of water, sand or other proppant and chemical additives under pressure into the targeted subsurface formations to fracture the surrounding rock and stimulate production. We routinely use hydraulic fracturing techniques in many of our drilling and completion programs. Hydraulic fracturing continues to be controversial in certain parts of the country, resulting in increased scrutiny and regulation of the hydraulic fracturing process, including by federal and state agencies and local municipalities. See “Item 1. Business—Regulation—Environmental and occupational health and safety regulation” for more discussion on these hydraulic fracturing matters. The adoption of any federal, state or local laws or the implementation of regulations or issuance of executive orders restricting hydraulic fracturing activities or locations or suspending or delaying the performance of hydraulic fracturing on federal properties or other locations could potentially result in an increase in our and our customers’ compliance costs, a decrease in the completion of our or our customers’ new crude oil and natural gas wells, and a decrease in demand for our midstream services, which could have a material adverse effect on our liquidity, results of operations, and financial condition. Restrictions, delays or bans on hydraulic fracturing could also reduce the amount of crude oil and natural gas that we or our customers are ultimately able to produce in commercial quantities, which adversely impacts our revenues and profitability. Our ability to produce crude oil and natural gas economically and in commercial quantities could be impaired if we are unable to acquire adequate supplies of water for our drilling and completion operations or are unable to dispose of or recycle the water we use economically and in an environmentally safe manner. Water is an essential component of shale crude oil and natural gas production during both the drilling and hydraulic fracturing processes. Our access to water to be used in these processes may be adversely affected due to reasons such as periods of extended drought, private, third-party competition for water in localized areas or the implementation of local or state governmental programs to monitor or restrict the beneficial use of water subject to their jurisdiction for hydraulic fracturing to assure adequate local water supplies. The occurrence of these or similar developments may result in limitations being placed on allocations of water due to needs by third-party businesses with more senior contractual or permitting rights to the water. Our inability to locate or contractually acquire and sustain the receipt of sufficient amounts of water could adversely impact our E&P operations or midstream services and have a corresponding adverse effect on our business, financial condition and results of operations. Additionally, operations associated with our production and development activities generate drilling muds, produced waters and other waste streams, some of which may be disposed of by means of injection into underground wells situated in non-producing subsurface formations. These injection wells are regulated pursuant to the UIC program established under the SDWA. See “Item 1. Business—Regulation—Environmental and occupational health and safety regulation” for more discussion on seismicity matters. Compliance with current and future environmental laws, executive orders, regulations and permit requirements governing the withdrawal, storage and use of surface water or groundwater necessary for hydraulic fracturing activities, the injection of waste streams into disposal wells, or any inability to secure transportation and access to disposal wells with sufficient capacity to accept all of our or our customers’ flowback and produced water on economic terms may increase our or our customers’ operating costs and cause delays, interruptions or termination of our or our customers’ operations, the extent of which cannot be predicted but that could be materially adverse to our business and results of operations. 42 T able of Contents Federal and state legislative and regulatory initiatives relating to pipeline safety that require the use of new or more stringent safety controls, substantial changes to existing integrity management programs or more stringent enforcement of applicable legal requirements could subject us to increased capital and operating costs and operational delays. Certain of our pipelines are subject to regulation by PHMSA under the HLPSA with respect to crude oil and condensate and the NGPSA with respect to natural gas. Those pipeline systems are required to maintain compliance with applicable pipeline integrity management programs. Additionally, those pipeline systems are subject to pipeline safety requirements that may impose more stringent safety obligations, require installation of new or modified safety controls, or perform capital or operating projects on an accelerated basis. New legislation or regulations adopted by PHMSA may impose more stringent requirements applicable to integrity management programs and other pipeline safety aspects of our operations, which could cause us to incur increased capital and operating costs and operational delays. See “Item 1. Business—Regulation—Pipeline safety regulation” for more discussion on pipeline safety matters. Our compliance with these applicable PHMSA pipeline safety requirements could have a material adverse effect on our operations, financial position, cash flows and our ability to maintain current distribution levels to the unitholders of OMP to the extent the increased costs are not recoverable through rates. We do not own all of the land on which our pipelines and associated facilities are located, which could result in disruptions to our operations. We do not own all of the land on which our pipelines and associated facilities have been constructed, and we are, therefore, subject to the possibility of more onerous terms and/or increased costs to retain necessary land use if we do not have valid rights-of-way or if such rights-of-way lapse or terminate. We obtain the rights to construct and operate our pipelines on land owned by third parties and governmental agencies for a specific period of time. Additionally, the federal Tenth Circuit Court of Appeals has held that tribal ownership of even a very small fractional interest in an allotted land, that is, tribal land owned or at one time owned by an individual Indian landowner, bars condemnation of any interest in the allotment. Consequently, the inability to condemn such allotted lands under circumstances where an existing pipeline rights-of-way may soon lapse or terminate serves as an additional impediment for pipeline operators. We cannot guarantee that we will always be able to renew existing rights-of-way or obtain new rights-of-way without experiencing significant costs. Any loss of rights with respect to our real property, through our inability to renew right-of-way contracts or otherwise, could have a material adverse effect on our business, results of operations, financial position and ability to make cash distributions to the unitholders of OMP. Competition in the oil and gas industry is intense, making it more difficult for us to acquire properties, market crude oil and natural gas and secure trained personnel. Our ability to acquire additional drilling locations and to find and develop reserves in the future will depend on our ability to evaluate and select suitable properties and to consummate transactions in a highly competitive environment for acquiring properties, market crude oil and natural gas and secure equipment and trained personnel. Also, there is substantial competition for capital available for investment in the oil and gas industry. Many of our competitors possess and employ financial, technical and personnel resources substantially greater than ours. Those companies may be able to pay more for productive oil and gas properties and exploratory drilling locations or to identify, evaluate, bid for and purchase a greater number of properties and locations than our financial or personnel resources permit. Furthermore, these companies may also be better able to withstand the financial pressures of unsuccessful drilling attempts, sustained periods of volatility in financial markets and generally adverse global and industry-wide economic conditions, and may be better able to absorb the burdens resulting from changes in relevant laws and regulations, which would adversely affect our competitive position. In addition, companies may be able to offer better compensation packages to attract and retain qualified personnel than we are able to offer. The cost to attract and retain qualified personnel has increased in recent years due to competition and may increase substantially in the future. Further, the COVID-19 pandemic that began in early 2020 provides an illustrative example of how a pandemic or epidemic can also impact our operations and business by affecting the health of these qualified or trained personnel and rendering them unable to work or travel. We may not be able to compete successfully in the future in acquiring prospective reserves, developing reserves, marketing hydrocarbons, attracting and retaining qualified personnel and raising additional capital, which could have a material adverse effect on our business. The loss of senior management or technical personnel could adversely affect our operations. To a large extent, we depend on the services of our senior management and technical personnel. The loss of the services of our senior management or technical personnel could have a material adverse effect on our operations. The public health concerns posed by COVID-19 could pose a risk to our personnel and may render our personnel unable to work or travel. The extent to which COVID-19 may impact our personnel, and subsequently our business, cannot be predicted at this time. We continue to monitor the situation, have actively implemented policies and practices to address the situation, and may adjust our current policies and practices as more information and guidance become available. We do not maintain, nor do we plan to obtain, any insurance against the loss of any of these individuals. 43 T able of Contents Seasonal weather conditions adversely affect our ability to conduct drilling activities in some of the areas where we operate. Our crude oil and natural gas operations are adversely affected by seasonal weather conditions. In the Williston Basin, drilling and other crude oil and natural gas activities cannot be conducted as effectively during the winter months. Severe winter weather conditions limit and may temporarily halt our ability to operate during such conditions. Results of operations in the Permian Basin may also be negatively affected by inclement weather during the winter months to a lesser extent. These constraints and the resulting shortages or high costs could delay or temporarily halt our operations and materially increase our operating and capital costs. We may be subject to risks in connection with acquisitions because of uncertainties in evaluating recoverable reserves, well performance and potential liabilities, as well as uncertainties in forecasting crude oil and natural gas prices and future development, production and marketing costs, and the integration of significant acquisitions may be difficult. We periodically evaluate acquisitions of reserves, properties, prospects and leaseholds and other strategic transactions that appear to fit within our overall business strategy. The successful acquisition of producing properties requires an assessment of several factors, including: • recoverable reserves; • future crude oil and natural gas prices and their appropriate differentials; • development and operating costs; • potential for future drilling and production; • validity of the seller’s title to the properties, which may be less than expected at the time of signing the purchase agreement; and • potential environmental and other liabilities, together with associated litigation of such matters. The accuracy of these assessments is inherently uncertain. In connection with these assessments, we perform a review of the subject properties that we believe to be generally consistent with industry practices. Our review will not reveal all existing or potential problems nor will it permit us to become sufficiently familiar with the properties to fully assess their deficiencies and potential recoverable reserves. Inspections may not always be performed on every well, and environmental problems are not necessarily observable even when an inspection is undertaken. Even when problems are identified, the seller may be unwilling or unable to provide effective contractual protection against all or part of the problems. We often are not entitled to contractual indemnification for environmental liabilities or title defects in excess of the amounts claimed by us before closing and acquire properties on an “as is” basis. Indemnification from the sellers will generally be effective only during a limited time period after the closing and subject to certain dollar limitations and minimums. We may not be able to collect on such indemnification because of disputes with the sellers or their inability to pay. Moreover, there is a risk that we could ultimately be liable for unknown obligations related to acquisitions, which could materially adversely affect our financial condition, results of operations or cash flows. Significant acquisitions and other strategic transactions may involve other risks, including: • diversion of our management’s attention to evaluating, negotiating and integrating significant acquisitions and strategic transactions; • the challenge and cost of integrating acquired operations, information management and other technology systems and business cultures with those of our operations while carrying on our ongoing business; • difficulty associated with coordinating geographically separate organizations; • an inability to secure, on acceptable terms, sufficient financing that may be required in connection with expanded operations and unknown liabilities; and • the challenge of attracting and retaining personnel associated with acquired operations. The process of integrating assets could cause an interruption of, or loss of momentum in, the activities of our business. Members of our senior management may be required to devote considerable amounts of time to this integration process, which will decrease the time they will have to manage our business. If our senior management is not able to effectively manage the integration process, or if any significant business activities are interrupted as a result of the integration process, our business could suffer. The success of an acquisition will depend, in part, on our ability to realize anticipated opportunities from combining the acquired assets or operations with those of ours. Even if we successfully integrate the assets acquired, it may not be possible to realize the full benefits we may expect in estimated proved reserves, production volume, cost savings from operating synergies or other benefits anticipated from an acquisition or realize these benefits within the expected time frame. Anticipated benefits of an acquisition may be offset by operating losses relating to changes in commodity prices, in oil and gas industry conditions, by risks and uncertainties relating to the exploratory prospects of the combined assets or operations, failure 44 T able of Contents to retain key personnel, an increase in operating or other costs or other difficulties. If we fail to realize the benefits we anticipate from an acquisition, our results of operations and stock price may be adversely affected. We may incur losses as a result of title defects in the properties in which we invest. It is our practice in acquiring crude oil and natural gas leases or interests not to incur the expense of retaining lawyers to examine the title to the mineral interest. Rather, we rely upon the judgment of crude oil and natural gas lease brokers or landmen who perform the fieldwork in examining records in the appropriate governmental office before attempting to acquire a lease in a specific mineral interest. Prior to the drilling of a crude oil or natural gas well, however, it is the normal practice in our industry for the person or company acting as the operator of the well to obtain a preliminary title review to ensure there are no obvious defects in the title to the well. Frequently, as a result of such examinations, certain curative work must be done to correct defects in the marketability of the title, and such curative work entails expense. Our failure to cure any title defects may adversely impact our ability in the future to increase production and reserves. There is no assurance that we will not suffer a monetary loss from title defects or title failure. Additionally, undeveloped acreage has greater risk of title defects than developed acreage. If there are any title defects or defects in assignment of leasehold rights in properties in which we hold an interest, we will suffer a financial loss. Disputes or uncertainties may arise in relation to our royalty obligations. Our production is subject to royalty obligations which may be prescribed by government regulation or by contract. These royalty obligations may be subject to changes in interpretation as business circumstances change and the law in jurisdictions in which we operate continues to evolve. For example, in 2019, the Supreme Court of North Dakota issued an opinion indicating a change in its interpretation of how certain gas royalty payments are calculated under North Dakota law with respect to certain state leases, which may require us to make additional royalty payments and reduce our revenues. Such changes in interpretation could have a material adverse effect on our business, financial condition, results of operations and cash flows. In addition, such changes in interpretation could result in legal or other proceedings. Please see “We are from time to time involved in legal, governmental and regulatory proceedings that could result in substantial liabilities” for a discussion of risks related to such proceedings. Risks related to our financial position Increased costs of capital could adversely affect our business. Our business and operating results can be harmed by factors such as the availability, terms and cost of capital, increases in interest rates or a reduction in credit rating. Changes in any one or more of these factors could cause our cost of doing business to increase, limit our access to capital, limit our ability to pursue acquisition opportunities, reduce our cash flows available for drilling and place us at a competitive disadvantage. Recent and continuing disruptions and volatility in the global financial markets may lead to an increase in interest rates or a contraction in credit availability impacting our ability to finance our operations. We require continued access to capital. A significant reduction in the availability of credit could materially and adversely affect our ability to achieve our planned operating results. Our revolving credit facilities contain operating and financial restrictions that may restrict our business and financing activities. Our revolving credit facilities, including the Oasis Credit Facility and the OMP Credit Facility, contain a number of restrictive covenants that impose significant operating and financial restrictions on us, including restrictions on our ability to, among other things: • sell assets, including equity interests in our subsidiaries; • pay distributions on, redeem or repurchase our common stock or redeem or repurchase our debt; • make investments; • incur or guarantee additional indebtedness or issue preferred stock; • create or incur certain liens; • make certain acquisitions and investments; • redeem or prepay other debt; • enter into agreements that restrict distributions or other payments from our restricted subsidiaries to us; • consolidate, merge or transfer all or substantially all of our assets; 45 T able of Contents • engage in transactions with affiliates; • create unrestricted subsidiaries; • enter into sale and leaseback transactions; and • engage in certain business activities. As a result of these covenants, we are limited in the manner in which we conduct our business, and we may be unable to engage in favorable business activities or finance future operations or capital needs. Our ability to comply with some of the covenants and restrictions contained in our revolving credit facilities may be affected by events beyond our control. If market or other economic conditions deteriorate or if crude oil, natural gas and NGL prices decline substantially or for an extended period of time from their current levels, our ability to comply with these covenants may be impaired. A failure to comply with the covenants, ratios or tests in our revolving credit facilities or any future indebtedness could result in an event of default under our revolving credit facilities or our future indebtedness, which, if not cured or waived, could have a material adverse effect on our business, financial condition and results of operations. If an event of default under either of our revolving credit facilities occurs and remains uncured, the lenders under the applicable Revolving Credit Facility: • would not be required to lend any additional amounts to us; • could elect to declare all borrowings outstanding, together with accrued and unpaid interest and fees, to be due and payable; • may have the ability to require us to apply all of our available cash to repay these borrowings; or • may prevent us from making debt service payments under our other agreements. Our obligations under the Oasis Credit Facility are collateralized by perfected first priority liens and security interests on substantially all of our oil and gas assets, including mortgage liens on oil and gas properties having at least 90% of the reserve value as determined by reserve reports, and if we are unable to repay our indebtedness under the Oasis Credit Facility, the lenders could seek to foreclose on our assets. OMP’s obligations under the OMP Credit Facility are collateralized by mortgages and other security interests on substantially all of OMP’s and its subsidiaries’ properties and assets, including the equity interests in all present and future subsidiaries (subject to certain exceptions). Some or all of the collateral owned by Bobcat DevCo and Beartooth DevCo is subject to an intercreditor agreement between Wells Fargo Bank, National Association (“Wells Fargo”), as administrative agent for the OMP Credit Facility, and Wells Fargo as the administrative agent for the Oasis Credit Facility, and acknowledged by Oasis Midstream Services LLC, Bobcat DevCo and Beartooth DevCo. If OMP is unable to repay its indebtedness under the OMP Credit Facility, the lenders could seek to foreclose on OMP’s assets. However, there are no cross-default rights between the Oasis Credit Facility and the OMP Credit Facility. Therefore, an acceleration of the OMP Credit Facility will not trigger automatically an acceleration of the Oasis Credit Facility, and vice versa. Please see “Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources.” Our level of indebtedness may increase and reduce our financial flexibility. As of December 31, 2020 (Successor), we had $260.0 million of outstanding borrowings and $6.8 million of outstanding letters of credit under the Oasis Credit Facility, $450.0 million of outstanding borrowings and a de minimis outstanding letter of credit under the OMP Credit Facility, and an aggregate amount of $433.2 million available for future secured borrowings under the revolving credit facilities. Please see “Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources.” In the future, we may incur significant indebtedness in order to make future acquisitions or to develop our properties. An increase in our level of indebtedness could affect our operations in several ways, including the following: • a significant portion of our cash flows could be used to service our indebtedness; • a high level of debt would increase our vulnerability to general adverse economic and industry conditions; • the covenants contained in the agreements governing our outstanding indebtedness limit our ability to borrow additional funds, dispose of assets, pay dividends and make certain investments; • our debt covenants may also affect our flexibility in planning for, and reacting to, changes in the economy and in our industry; • a high level of debt may place us at a competitive disadvantage compared to our competitors that are less leveraged and therefore, may be able to take advantage of opportunities that our indebtedness would prevent us from pursuing; 46 T able of Contents • a high level of debt may make it more likely that a reduction in our borrowing base under the Oasis Credit Facility following a periodic redetermination could require us to repay a portion of our then-outstanding bank borrowings; and • a high level of debt may impair our ability to obtain additional financing in the future for working capital, capital expenditures, acquisitions, general corporate or other purposes. A high level of indebtedness would increase the risk that we may default on our debt obligations. Our ability to meet our debt obligations and to maintain or reduce our level of indebtedness depends on our future performance. General economic conditions, crude oil, natural gas and NGL prices and financial, business and other factors affect our operations and our future performance. Many of these factors are beyond our control. If crude oil, natural gas and NGL prices decline substantially or for an extended period of time from their current levels, we may not be able to generate sufficient cash flows to pay the interest on our debt and future working capital, and borrowings or equity financing may not be available to pay or refinance such debt. Factors that will affect our ability to raise cash through an offering of our capital stock or a refinancing of our debt include financial market conditions, the value of our assets and our performance at the time we need capital. In addition, the Oasis Credit Facility borrowing base is subject to periodic redeterminations. We could be forced to repay a portion of our bank borrowings under the Oasis Credit Facility due to redeterminations of our borrowing base. If we are forced to do so, we may not have sufficient funds to make such repayments. If we do not have sufficient funds and are otherwise unable to negotiate renewals of our borrowings or arrange new financing, we may have to sell significant assets. Any such sale could have a material adverse effect on our business and financial results. We may not be able to generate enough cash flows to meet our debt obligations. We expect our earnings and cash flows to vary significantly from year to year due to the nature of our industry. As a result, the amount of debt that we can manage in some periods may not be appropriate for us in other periods. Additionally, our future cash flows may be insufficient to meet our debt obligations and other commitments. Any insufficiency could negatively impact our business. A range of economic, competitive, business and industry factors will affect our future financial performance, and, as a result, our ability to generate cash flows from operations and to pay our debt obligations. Many of these factors, such as crude oil, natural gas and NGL prices, economic and financial conditions in our industry and the global economy and initiatives of our competitors, are beyond our control. Specifically, the actions of OPEC and other non-OPEC, oil-producing countries, including Russia, have caused substantial increases in the global supply of crude oil which have contributed to sharp declines in crude oil prices in 2020, and therefore negatively affected our ability to generate cash flows from operations. In addition, economic recessions, including those brought on by the COVID-19 pandemic, have a negative effect on the demand for crude oil and natural gas and will and have had a negative effect on our ability to generate cash flows from operations. If we do not generate enough cash flows from operations to satisfy our debt obligations, we may have to undertake alternative financing plans, such as: • selling assets; • reducing or delaying capital investments; • seeking to raise additional capital; or • refinancing or restructuring our debt. If for any reason we are unable to meet our debt service and repayment obligations, we would be in default under the terms of the agreements governing our debt, which would allow our creditors at that time to declare all outstanding indebtedness to be due and payable, and our lenders could compel us to apply all of our available cash to repay our borrowings. If amounts outstanding under our revolving credit facilities were to be accelerated, we cannot be certain that our assets would be sufficient to repay in full the money owed to the lenders or to our other debt holders. Please see “Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources.” Our derivative activities could result in financial losses or could reduce our income. To achieve more predictable cash flows and to reduce our exposure to adverse fluctuations in the prices of crude oil and natural gas, we currently, and may in the future, enter into derivative arrangements for a portion of our crude oil and natural gas production, including collars and fixed-price swaps. We have not designated any of our derivative instruments as hedges for accounting purposes and record all derivative instruments on our balance sheet at fair value. Changes in the fair value of our derivative instruments are recognized in earnings. Accordingly, our earnings may fluctuate significantly as a result of changes in the fair value of our derivative instruments. Derivative arrangements also expose us to the risk of financial loss in some circumstances, including when: • production is less than the volume covered by the derivative instruments; • the counterparty to the derivative instrument defaults on its contract obligations; or 47 T able of Contents • there is an increase in the differential between the underlying price in the derivative instrument and actual price received. In addition, some of these types of derivative arrangements limit the benefit we would receive from increases in the prices for crude oil and natural gas and may expose us to cash margin requirements. Our exploration, development and exploitation projects require substantial capital expenditures. We may be unable to obtain needed capital or financing on satisfactory terms, which could lead to expiration of our leases or a decline in our estimated net crude oil and natural gas reserves. Our exploration and development activities are capital intensive. We make and expect to continue to make substantial capital expenditures in our business for the development, exploitation, production and acquisition of crude oil and natural gas reserves. DeGolyer and MacNaughton projects that we will incur capital costs of $463.3 million over the next five years to develop the proved undeveloped reserves in the Williston and Permian Basins covered by its December 31, 2020 reserve report. Additionally, OMP will continue to invest in midstream assets to support our E&P business segment as well as third-party customers. Please see “Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources” for more information about our capital expenditures. The actual amount and timing of our future capital expenditures may differ materially from our estimates as a result of, among other things, commodity prices, actual drilling results, the availability of drilling rigs and other services and equipment, and regulatory, technological and competitive developments. We intend to finance our future capital expenditures primarily through cash flows provided by operating activities, borrowings under our revolving credit facilities and cash settlements of derivative contracts; however, our financing needs may require us to alter or increase our capitalization substantially through the issuance of additional debt or equity securities or the sale of non-strategic assets. The issuance of additional debt or equity may require that a portion of our cash flows provided by operating activities be used for the payment of principal and interest on our debt, thereby reducing our ability to use cash flows to fund working capital, capital expenditures and acquisitions or to pay dividends. The issuance of additional equity securities could have a dilutive effect on the value of our common stock. In addition, upon the issuance of certain debt securities (other than on a borrowing base redetermination date), our borrowing base under the Oasis Credit Facility will be automatically reduced by an amount equal to 25% of the aggregate principal amount of such debt securities. Our cash flows provided by operating activities and access to capital are subject to a number of variables, including: • our estimated net proved reserves; • the level of crude oil, natural gas and NGLs we are able to produce from existing wells and new projected wells; • the prices at which our crude oil, natural gas and NGLs are sold; • the costs of developing and producing our crude oil and natural gas production; • our ability to acquire, locate and produce new reserves; • the ability and willingness of our banks to lend; and • our ability to access the equity and debt capital markets. If the borrowing base under our Oasis Credit Facility or our revenues decrease as a result of low crude oil, natural gas or NGL prices, operating difficulties, declines in reserves or for any other reason, we may have limited ability to obtain the capital necessary to sustain our operations at current levels. If additional capital is needed, we may not be able to obtain debt or equity financing on terms favorable to us, or at all. If cash generated by operations or cash available under our Oasis Credit Facility is not sufficient to meet our capital requirements, the failure to obtain additional financing could result in a curtailment of our operations relating to development of our drilling locations, which in turn could lead to a possible expiration of our leases and a decline in our estimated net proved reserves, and could adversely affect our business, financial condition and results of operations. The inability of one or more of our customers or affiliates to meet their obligations to us may adversely affect our financial results. Our principal exposures to credit risk are through receivables resulting from the sale of our crude oil and natural gas production ($161.5 million in receivables at December 31, 2020), which we market to energy marketing companies, other producers, power generators, local distribution companies, refineries and affiliates, and joint interest receivables ($31.9 million at December 31, 2020). We are subject to credit risk due to the concentration of our crude oil and natural gas receivables with several significant customers. This concentration of customers may impact our overall credit risk since these entities may be similarly affected by changes in economic and other conditions. For the Successor period of November 20, 2020 through December 31, 2020, sales 48 T able of Contents to ExxonMobil Oil Corporation and Phillips 66 Company accounted for approximately 22% and 15%, respectively, of our total product sales. For the Predecessor period of January 1, 2020 through November 19, 2020, Phillips 66 Company and Gunvor USA LLC accounted for approximately 11% and 10%, respectively, of our total product sales. For the year ended December 31, 2019, sales to Phillips 66 Company accounted for approximately 14% of our hydrocarbon product sales. No other purchasers accounted for more than 10% of our total sales in 2020 or 2019. For the year ended December 31, 2018, no purchaser accounted for more than 10% of our total sales. We do not require all of our customers to post collateral. The inability or failure of our significant customers to meet their obligations to us or their insolvency or liquidation may adversely affect our financial results. Joint interest receivables arise from billing entities who own a partial interest in the wells we operate. These entities participate in our wells primarily based on their ownership in leases on which we choose to drill. We have limited ability to control participation in our wells. For the year ended December 31, 2020, we recorded a credit of $0.2 million for changes in our estimate of expected credit losses. In addition, our crude oil and natural gas derivative arrangements expose us to credit risk in the event of nonperformance by counterparties. Derivative assets and liabilities arising from derivative contracts with the same counterparty are reported on a net basis, as all counterparty contracts provide for net settlement. At December 31, 2020, we had derivatives in place with eight counterparties and a total net derivative liability of $94.1 million. We may not be able to utilize a portion of our net operating losses (“NOLs”) to offset future taxable income for U.S. federal or state tax purposes, which could adversely affect our financial position, results of operations and cash flows. As of December 31, 2020, we had significant federal and state income tax NOLs. Utilization of these NOLs depends on many factors, including our future taxable income, which cannot be assured. As a result of our emergence from the Chapter 11 Cases and related transactions, our NOLs will be reduced by the amount of discharge of indebtedness income we recognized under Section 108 of the Internal Revenue Code of 1986, as amended (the “Code”). Following such reduction, the federal NOLs are not subject to expiration, however the state NOLs will begin to expire in 2023. If a corporation experiences an “ownership change,” any NOLs, losses or deductions attributable to a “net unrealized built-in loss” and other tax attributes could be substantially limited, and timing of the usage of such tax attributes could be substantially delayed, under Section 382 of the Code (“Section 382”). A corporation generally will experience an ownership change if one or more stockholders (or group of stockholders) who are each deemed to own at least 5% of the corporation’s stock increase their ownership by more than 50 percentage points over their lowest ownership percentage within a rolling three-year period. As a result of our emergence from the Chapter 11 Cases and related transactions, we experienced an ownership change that subjected certain of our tax attributes, including NOLs, to limitations under Section 382. Determining the limitations under Section 382 is technical and highly complex, and no assurance can be given that upon further analysis our ability to take advantage of our NOLs may be limited to a greater extent than we currently anticipate. If we are limited in our ability to use our NOLs in future years in which we have taxable income, we will pay more taxes than if we were able to utilize our NOLs fully, which could have a negative impact on our financial position, results of operations and cash flows. Additionally, we may experience ownership changes in the future as a result of subsequent shifts in our stock ownership that we cannot predict or control that could result in further limitations being placed on our ability to utilize our federal NOLs, which could adversely affect our financial position, results of operations and cash flows. The enactment of derivatives legislation and regulation could have an adverse effect on our ability to use derivative instruments to reduce the negative effect of commodity price changes, interest rate and other risks associated with our business. On July 21, 2010, new comprehensive financial reform legislation, known as the Dodd-Frank Wall Street Reform and Consumer Protection Act (the “Dodd-Frank Act”), was enacted that establishes federal oversight and regulation of the over-the-counter derivatives market and entities, such as us, that participate in that market. The Dodd-Frank Act requires the CFTC, the SEC and other regulators to promulgate rules and regulations implementing the new legislation. In its rulemaking under the Dodd-Frank Act, the CFTC has proposed new regulations to set position limits for certain futures, options and swap contracts in designated physical commodities, including, among others, crude oil and natural gas. The Dodd-Frank Act and CFTC rules have also designated certain types of swaps (thus far, only certain interest rate swaps and credit default swaps) for mandatory clearing and exchange trading, and may designate other types of swaps for mandatory clearing and exchange trading in the future. To the extent that we engage in such transactions or transactions that become subject to such rules in the future, we will be required to comply with the clearing and exchange trading requirements or to take steps to qualify for an exemption to such requirements. In addition, certain banking regulators and the CFTC have adopted final rules establishing minimum margin requirements for uncleared swaps. Although we expect to qualify for the non-financial end-user exception from margin requirements for swaps to other market participants, such as swap dealers, these rules may change the cost and availability of the swaps we use for hedging. If any of our swaps do not qualify for the non-financial end-user exception, we could be required 49 T able of Contents to post initial or variation margin, which would impact liquidity and reduce our cash. This would in turn reduce our ability to execute hedges to reduce risk and protect cash flows. Other regulations to be promulgated under the Dodd-Frank Act also remain to be finalized. As a result, it is not possible at this time to predict with certainty the full effects of the Dodd-Frank Act and CFTC rules on us and the timing of such effects. The Dodd-Frank Act and regulations could significantly increase the cost of derivative contracts, materially alter the terms of derivative contracts, reduce the availability of derivatives to protect against risks we encounter, reduce our ability to monetize or restructure our existing derivative contracts, and increase our exposure to less creditworthy counterparties. If we reduce our use of derivatives as a result of the Dodd-Frank Act and regulations, our results of operations may become more volatile and our cash flows may be less predictable, which could adversely affect our ability to plan for and fund capital expenditures. Further, to the extent our revenues are unhedged, they could be adversely affected if a consequence of the Dodd-Frank Act and implementing regulations is to lower commodity prices. Any of these consequences could have a material adverse effect on our financial position, results of operations and cash flows. In addition, the European Union and other non-U.S. jurisdictions are implementing regulations with respect to the derivatives market. To the extent we transact with counterparties in foreign jurisdictions, we may become subject to such regulations. Risks related to our common stock Our ability to declare and pay dividends is subject to certain considerations and limitations. We declared a dividend of $0.375 per share of common stock payable on March 22, 2021 to shareholders of record as of March 8, 2021. Any payment of future dividends will be at the discretion of our Board of Directors and will depend on, among other things, our earnings, financial condition, capital requirements, level of indebtedness, statutory and contractual restrictions applicable to the payment of dividends and other considerations that our Board of Directors deems relevant. Cash dividend payments in the future may only be made out of legally available funds and, if we experience substantial losses, such funds may not be available. Certain covenants in the Oasis Credit Facility may limit our ability to pay dividends. We can provide no assurance that we will continue to pay dividends at the current rate or at all. Our amended and restated certificate of incorporation and amended and restated bylaws, as well as Delaware law, contain provisions that could discourage acquisition bids or merger proposals, which may adversely affect the market price of our common stock. Our amended and restated certificate of incorporation authorizes our Board of Directors to issue preferred stock without stockholder approval. If our Board of Directors elects to issue preferred stock, it could be more difficult for a third party to acquire us. In addition, some provisions of our amended and restated certificate of incorporation and amended and restated bylaws could make it more difficult for a third party to acquire control of us, even if the change of control would be beneficial to our stockholders, including: • advance notice provisions for stockholder proposals and nominations for elections to the Board of Directors to be acted upon at meetings of stockholders; and • limitations on the ability of our stockholders to call special meetings. Delaware law prohibits us from engaging in any business combination with any “interested stockholder,” meaning generally that a stockholder who beneficially owns more than 15% of our stock cannot acquire us for a period of three years from the date this person became an interested stockholder, unless various conditions are met, such as approval of the transaction by our Board of Directors. The exercise of all or any number of outstanding warrants or the issuance of stock-based awards may dilute your holding of shares of our common stock. As of the date of filing this report, we have outstanding Warrants (as defined in “Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Recent Developments—Emergence from voluntary reorganization under Chapter 11”) to purchase approximately 1.6 million shares of our common stock at an initial exercise price of $94.57. In addition, as of December 31, 2020, approximately 2.4 million shares of our common stock were reserved for future issuance under the Oasis Petroleum Inc. 2020 Long Term Incentive Plan (the “2020 LTIP”). The exercise of equity awards, including any stock options that we may grant in the future, the Warrants, and the sale of shares of our common stock underlying any such options or Warrants, could have an adverse effect on the market for our common stock, including the price that an investor could obtain for their shares. There is a limited trading market for our common stock and the market price of our common stock is subject to volatility. Upon our emergence from bankruptcy, our Predecessor common stock was cancelled, and we issued new common stock. Since the Emergence Date, liquidity for our common shares has been below historical levels, reflecting a concentrated shareholder base, undeveloped market and fewer shares outstanding. The market price of the new common stock could be subject to wide fluctuations in response to, and the level of trading that develops with the new common stock may be affected by, numerous 50 T able of Contents factors, many of which are beyond our control. These factors include, among other things, our new capital structure as a result of the transactions contemplated by the Plan, our limited trading history subsequent to our emergence from bankruptcy, our limited trading volume, the concentration of holdings of our new common stock, the lack of comparable historical financial information due to our adoption of fresh start accounting, actual or anticipated variations in our operating results and cash flow, the nature and content of our earnings releases, announcements or events that impact our products, customers, competitors or markets, business conditions in our markets and the general state of the securities markets and the market for energy-related stocks, as well as general economic and market conditions and other factors that may affect our future results. General risk factors We are from time to time involved in legal, governmental and regulatory proceedings that could result in substantial liabilities. Like other similarly-situated oil and gas companies, we are from time to time involved in various legal, governmental and regulatory proceedings in the ordinary course of business including, but not limited to, commercial disputes, claims from royalty and surface owners, property damage claims, personal injury claims, regulatory compliance matters, disputes with tax authorities and other matters. The outcome of such matters often cannot be predicted with certainty. If our efforts to defend ourselves in legal, governmental and regulatory matters are not successful, it is possible the outcome of one or more such proceedings could result in substantial liability, penalties, sanctions, judgments, consent decrees or orders requiring a change in our business practices, which could have a material adverse effect on our business, financial condition, results of operations and cash flows. Judgments and estimates to determine accruals related to legal, governmental and regulatory proceedings could change from period to period, and such changes could be material. Terrorist attacks or cyber-attacks could have a material adverse effect on our business, financial condition or results of operations. Terrorist attacks or cyber-attacks may significantly affect the energy industry, including our operations and those of our potential customers, as well as general economic conditions, consumer confidence and spending and market liquidity. Strategic targets, such as energy-related assets, may be at greater risk of future attacks than other targets in the United States. Also, destructive forms of protests and opposition by extremists and other disruptions, including acts of sabotage or eco-terrorism, against crude oil and natural gas development and production or midstream processing or transportation activities could potentially result in damage or injury to persons, property or the environment or lead to extended interruptions of our operations. Our insurance may not protect us against such occurrences. Consequently, it is possible that any of these occurrences, or a combination of them, could have a material adverse effect on our business, financial condition and results of operations. A cyber incident could result in information theft, data corruption, operational disruption and/or financial loss . The oil and gas industry has become increasingly dependent on digital technologies to conduct day-to-day operations, including certain midstream activities. For example, software programs are used to manage gathering and transportation systems and for compliance reporting. The use of mobile communication devices has increased rapidly. Industrial control systems such as SCADA (supervisory control and data acquisition) now control large scale processes that can include multiple sites and long distances, such as crude oil and natural gas pipelines. We depend on digital technology, including information systems and related infrastructure as well as cloud applications and services, to process and record financial and operating data and to communicate with our employees and business partners. Our business partners, including vendors, service providers and financial institutions, are also dependent on digital technology. The technologies needed to conduct midstream activities make certain information the target of theft or misappropriation. As dependence on digital technologies has increased, cyber incidents, including deliberate attacks or unintentional events, also has increased. A cyber attack could include gaining unauthorized access to digital systems or data for purposes of misappropriating assets or sensitive information, corrupting data or causing operational disruption. SCADA-based systems are potentially vulnerable to targeted cyber attacks due to their critical role in operations. Our technologies, systems, networks and data, and those of our business partners, may become the target of cyber attacks or information security breaches that could result in the unauthorized release, gathering, monitoring, misuse, loss or destruction of proprietary and other information or other disruption of our business operations. In addition, certain cyber incidents, such as unauthorized surveillance or a cyber breach, may remain undetected for an extended period. A cyber incident involving our information systems or data and related infrastructure, or that of our business partners, including any vendor or service provider, could disrupt our business plans and negatively impact our operations in the following ways, among others: 51 T able of Contents • supply chain disruptions, which could delay or halt development of additional infrastructure, effectively delaying the start of cash flows from the project; • delays in delivering or failure to deliver product at the tailgate of our facilities, resulting in a loss of revenues; • operational disruption resulting in loss of revenues; • events of non-compliance that could lead to regulatory fines or penalties; and • business interruptions that could result in expensive remediation efforts, distraction of management, damage to our reputation or a negative impact on the price of our units. Our implementation of various controls and processes, including globally incorporating a risk-based cyber security framework, to monitor and mitigate security threats and to increase security for our information, facilities and infrastructure is costly and labor intensive. Moreover, there can be no assurance that such measures will be sufficient to prevent security breaches from occurring. As cyber threats continue to evolve, we may be required to expend significant additional resources to continue to modify or enhance our protective measures or to investigate and remediate any information security vulnerabilities. Ineffective internal controls could impact our business and financial results. Our internal control over financial reporting may not prevent or detect misstatements because of its inherent limitations, including the possibility of human error, the circumvention or overriding of controls, or fraud. Even effective internal controls can provide only reasonable assurance with respect to the preparation and fair presentation of financial statements. If we fail to maintain the adequacy of our internal controls, including any failure to implement required new or improved controls, or if we experience difficulties in their implementation, our business and financial results could be harmed and we could fail to meet our financial reporting obligations. Item 1B. Unresolved Staff Comments None. Item 2. Properties The information required by Item 2. is contained in Item 1. Business. Item 3. Legal Proceedings See “Part II, Item 8. Financial Statements and Supplementary Data—Note 24—Commitments and Contingencies” and “—Note 2—Emergence from Voluntary Reorganization under Chapter 11,” which are incorporated herein by reference, for a discussion of material legal proceedings. Item 4. Mine Safety Disclosures Not applicable. 52 T able of Contents PART II