Wednesday, January 8, 2025

An Introduction to Environmental Law and Policy: Summary and Review of Chapter 4 of Environmental Law, 5th Edition by Nancy K. Kubasek and Gary S. Silverman (Prentice Hall, 2005, pgs. 125-165)


     The authors first point out that the field of environmental law is recent. They also point out that the lack of environmental laws in the pre-environmental law period led to many negative environmental impacts that we are still cleaning up. An example I can think of is acid mine drainage. A 1977 law first began to deal with the problem in earnest.

     Before environmental laws protection relied on tort law. Obviously, this was not working and the need for environmental laws became widely acknowledged.  

     As in another environmental law book that I have, Garret Hardin’s story of the tragedy of the Commons is told. The ‘commons’ refers to something that is shared by all like a river, the atmosphere, or groundwater, and the ‘tragedy’ is polluting it. I am not a fan of Hardin due mainly to his other pessimistic ideas like “lifeboat ethics” where there is not enough for everyone so some should be allowed to perish for the rest of us. This has been proven to be nonsense. We have the technology and the wherewithal to help all and to limit our environmental impacts.

     Next the problem of the free rider is addressed where some benefit from the acknowledged public goods of clean air and clean water while others of their own volition pay to keep it that way. In that scenario there is no requirement to keep water and air clean, it is strictly voluntary. We need requirements. However, I think in many cases we also need voluntary actions, particularly among companies that pollute, and especially among companies that emit carbon.

     Pollution is considered to be an externality to business, but it is decidedly a negative externality. Nowadays, however, regulatory requirements and costs are built into business plans. Obviously, we need rules to limit and mitigate pollution. Not only the government but consumers as well demand it, even though in many cases that will result in a higher cost for those products. The text points out that the marketplace itself has no mechanism for ensuring low environmental impact so the government must do it.

     In discussing the ‘environmental ethic’ the authors note the importance of monitoring long-term impacts such as effects on ecosystems. They note that some environmentalists think we have a responsibility due to our knowledge:

Because we have superior understanding, we have special responsibilities to consider the long-term impacts of our behavior.”

     Next, they return to tort law and its inability to provide adequate environmental protection. Tort law was applied mostly to nuisance cases where one party complained that another polluted its land, air, or water. Previous cases have determined that the harm created by the nuisance must be balanced against the harm, usually economic, of ceasing the nuisance. It is a basic cost-benefit or harm-benefit consideration. The main issue is that pollution abatement is often expensive. However, in most cases we still need it. Some of these cases resulted in the pollution being produced unchecked and those affected being awarded compensation for the damage incurred. There are other problems with tort law including determining whether the nuisance is private or public and determining which polluting company is responsible for the particular impact. Cases must be proven and that takes environmental investigation which may be limited due to lack of resources and personnel. The last problem they note about tort law is that it is reactive in that the problem must be present and occurring before any action is taken. Obviously, we need some kind of preventive action when we know certain processes will pollute.

     Economic means of addressing pollution include subsidies, emissions charges, and marketable emissions permits. Government subsidization of pollution control is sometimes warranted. This may have additional positive effects such that when one company takes a subsidy to help pay for pollution abatement, they may demand that other companies in their industry do the same. Of course, if abatement is voluntary, requirements to abate are not fairly distributed. Thus, we need environmental laws to fairly distribute environmental liabilities. Emissions charges and so-called ‘green taxes’ are a disincentive to pollute. If it costs to pollute, then pollution abatement becomes more likely. Such charges can be difficult to assess, and the pollution also must be measured and monitored. Fees must be such that most companies can afford them. Marketable emissions permits allow companies to trade those permits and allowances to best provide environmental protection for the industry overall. These market mechanisms have worked for power plants but in other manifestations, the results have been mixed. They work better when all must comply. Otherwise, companies in one country, region, or state may have economic advantages over other companies simply because they are not held to the same pollution standards.

     Direct regulation, also called command-and-control regulation or end-of-pipe regulation, is the main means of enacting environmental law. The penalties of being out of compliance also give companies incentives to find ways to reduce pollution all along their supply and value chains. One interesting thing they note is advances in detection technology. Before 1970 when environmental law was essentially born in the U.S., we could only measure contaminants at levels such as parts per thousand. We can now measure some pollutants in parts per billion and in some cases parts per trillion.

     The authors mention three influential books from the 1960s and early 1970s: Rachel Carson’s ‘Silent Spring’, Paul Ehrlich’s ‘Population Bomb’ and Barry Commoner’s ‘Closing Circle.’ Carson showed that unabated pollution was creating environmental harms not yet acknowledged. Ehrlich’s work, though influential, turned out to be dead wrong, and resulted in more harm than good as it led to sterilization campaigns. Other obvious and visual signs of pollution such as big oil spills, the burning Cuyahoga River, and smog-filled cities brought environmental impacts out for all to see and experience. Some results were the creation of the U.S. EPA and the National Environmental Policy Act (NEPA) which requires environmental impact analysis before any major project is undertaken. They note that 27 laws and many administrative laws were enacted during the 1970s.

     The 1980s brought more concerns over the costs of environmental regulations. Reagan promoted deregulation and a pullback from previous regulation trends. Reagan cut staff and funding for the EPA and other regulatory agencies and relaxed enforcement actions. Both Bushes, Clinton, and Obama would later add to regulation while at the same time requiring analysis of the costs of regulation. Trump would cut staff, funding, and regulations as well. As in Reagan’s cuts, some were probably warranted and others not so much. Staffing and funding especially, and regulations too, are debatable in their details. I think Trump’s second EPA chief Andrew Wheeler did a better job than his first, Scott Pruit. Many in Congress found Reagan’s cuts to be an unacceptable lax attitude toward environmental impacts and moved to strengthen environmental laws. By the late 80s, the burden of environmental protection was shifting to the states. This was sensible and practical since most environmental impact is local or regional.

     During George H.W. Bush’s term in the early 1990s Congress was back to strengthening environmental laws and enforcement was up. Amendments to the Clean Air Act were enacted that required further compliance. Concerns about the cost of regulation returned. After big environmental gains in the 70s and 80s, progress became more incremental:

Each incremental gain would also provide fewer visible benefits. These factors helped to create a shift of environmental policy away from the end-of-pipe regulation toward more pollution prevention and the use of more cost-effective ways to reduce pollution.”

The shift in the 90s also brought more interest in utilizing market forces so pollution charges and marketable emissions permits became more common. The marketable permits enabled by the amended Clean Air Act of 1990 successful in letting industry share the burden of costs were generally in a way that was deemed fair by the participants. Voluntary compliance became more common and international standards that addressed environmental concerns like ISO 14000 were becoming more widely adopted.

     The history continues, describing Clinton and Gore’s work toward strengthening environmental laws and their GOP House, clawing them back in favor of business interests. This give and take has been happening since the time of Reagan, when Democrat administrations have favored strong environmental laws and GOP administrations have favored keeping laws from costing businesses (and consumers) too much. Often the law tweaks are enacted via executive orders. We are about to go through that cycle again as Biden moves to make large parts of offshore America free of seismic and drilling for oil and Trump will rescind those orders and many others as soon as he can. Realistically, all administrations will keep most environmental laws but change how they are administered and enforced. Congressional approval is required for most changes in the laws and statutes. In more recent times, businesses have been spending and preparing for strengthened laws on pollution and GHG emissions. Nobody really wants to go out and pollute for profit, they just don’t want to be so burdened that it affects their bottom line too much.

     In the 2000s George W. Bush championed states’ rights, property rights, and the oil industry. Bush’s EPA chief, Christine Todd Whitman was a moderate who was trumped by her bosses on some policies, but she resigned in 2003, for personal reasons. EPA resignations in disagreement with the Bush administration were common.

     The next section looks at the National Environmental Policy Act of 1970 and the Pollution Prevention Act of 1990.

 

The National Environmental Policy Act (NEPA) of 1970

     NEPA established the Council on Environmental Quality (CEQ) as a federal watchdog. It requires federal agencies to consider the environmental effects of decisions. It also requires that an Environmental Impact Statement (EIS) be prepared for every major legislative proposal or government action that could impact the environment. The CEQ consists of three people who advise the president on environmental matters. They are responsible for preparing the President’s Annual Report on Environmental Quality. The CEQ also reviews NEPA EIS requirements and EIS draft statements. Reagan decimated the CEQ's budget and staff. Clinton sought to elevate the EPA to cabinet level and have another agency replace the CEQ, but the idea was shot down by Congress, so he went back to the CEQ. From about 1983 to 2001 about 500 EISs were completed and published by federal agencies per year. I don’t know the data since then. The threshold for requiring an EIS has three criteria: 1) the action must be federal, whether partly financed by the government or requiring federal signoffs. 2) the federal activity must be major, usually defined as requiring a significant amount of financial and/or human resources. 3) the project must be deemed to have a significant environmental impact. That last requirement is vague and has been challenged many times. In 1979 the CEQ tried to make it easier to discern, focusing on the possibility of both short-term and long-term impacts. The text states that even with this clarification it is often difficult to determine if an EIS is necessary according to law.

Environmental impact statements remain controversial. Newspapers frequently report conflicts between environmental groups and businesses over the need for an EIS

NEPA’s EISs remain controversial today and are one of the major issues to be addressed in permit reform. The long-standing and well-founded complaint is that environmental groups have too much power to sue and delay projects due to EISs. Due to staffing shortages at federal agencies and the time it takes for EISs, some projects are delayed by many years or even a decade. The average in recent years is 4.2 years, and this is often just to get approval to begin projects. Clearly, this hampers businesses and their ability to advance important projects in a timely manner. In my and many others’ opinions, NEPA has been soundly abused by environmentalists to delay needed projects to the detriment of our economy and technological advancement. Many on the political left and most on the political right agree. Jurisdiction is often a factor since judges in certain districts are more or less likely to side with environmentalists. In cases where the need for an EIS is not established a Finding of No Significant Impact (FONSI) may be filed by federal agencies to prevent opposition. An EIS is prepared by government agencies with the help of consultants. Then a draft statement is prepared and often debated among those involved. EPA has a system to rate EISs as shown below.

 






     The draft statement may be rejected and a new draft statement drawn up after debate. After the EIS is worked out it is published in the Federal Register and a public comment period ensues. The text notes that routinely for an EIS, this procedure often takes from six to nine months, and if challenged in court it could take a year or longer. As noted, nowadays, to get there from the beginning of the process takes an average of 4.2 years. If an EIS is deemed inadequate, a temporary injunction may be filed until an approved EIS is produced. Outcomes include: 1) the project is modified to address concerns in the EIS, 2) the delay leads to cementing public opposition to the project, and 3) the delay may make the project too costly, and the project may be dropped. As many have noted, the injunctions are rare, usually less than 10% of projects, but still manage to delay them considerably and cause economic harm. Citizens’ groups and environmental groups are most often the plaintiffs in such cases.

     An EIS consists of

1)        A statement of environmental impacts (positive and negative) of the proposed action.

2)        Any unavoidable adverse environmental impacts should the proposal be implemented.

3)        Alternatives to the proposal (including taking no action).

4)        The relationship between short-term uses of the environment and enhancement of long-term productivity.

5)        Any reversible commitments of resources.

     An Environmental Assessment (EA)may be used in place of an EIS if an EIS is deemed unnecessary. If challenged, the EA is often used to show that an EIS is not necessary. EAs are faster and represent a reasonable way to do environmental due diligence in most cases. By 1993 about 50,000 EAs were being prepared annually, and that number is surely much higher today. Even 20 years ago when this edition of the text was published, it was noted that EISs were too time-consuming and too expensive. Add to that the litigation (often frivolous IMO) and the costs and time can go up considerably more.

 

Pollution Prevention Act of 1990

     The Pollution Prevention Act departs from command-and-control end-of-pipe direct environmental laws toward the prevention of pollution. Early implementation of environmental laws was effective as the ‘low-hanging fruit’ of abatement was addressed, resulting in great improvements at low costs. However, additional improvements, deemed necessary for protecting human health and the environment, would be more expensive to implement and would result in less impressive gains. This act focuses on source reduction or prevention. Section 2 of the act notes:

1)        There are significant opportunities for industry to reduce or prevent pollution at the source through cost-effective changes in production, operation, and raw materials use. Such changes offer industry substantial savings in reduced raw material, pollution control, and liability costs as well as help protect the environment and reduce risks to worker health and safety.

2)        The opportunities for source reduction are often not realized because existing regulations, and the industrial resources they require for compliance, focus upon treatment and disposal, rather than source reduction; existing regulations do not emphasize multimedia management of pollution; and businesses need information and technical assistance to overcome institutional barriers to the adoption of source reduction practices.

3)        Source reduction is fundamentally different and more desirable than waste management and pollution control. The Environmental Protection Agency needs to address the historical lack of attention to source reduction.

      

Pollution should be prevented or reduced at the source whenever feasible; pollution that cannot be prevented should be recycled in an environmentally safe manner, whenever feasible; pollution that cannot be prevented or recycled should be treated in an environmentally safe manner. whenever feasible; and disposal or other release into the environment should be employed only as a last resort and should be conducted in an environmentally safe manner.

The program provides matching grants to states for source reduction projects. In 1993 Clinton issued an executive order with three main requirements as shown below.

1)        Each federal agency must develop a pollution prevention strategy that is committed to source reduction.

2)        Each agency must reduce total releases of toxic chemicals by percent by the end of 1999.

3)        Each agency must establish a plan to eliminate the procurement of hazardous substances for agency use

The EPA suggests that companies develop a pollution prevention program that also includes waste management and periodically assess and monitor pollution and waste. They should also develop cost allocation systems for pollution abatement and waste management and utilize the best available technology (BAT) when possible. Pollution prevention should be a part of a company’s basic strategy. Thus, the Pollution Prevention Act of 1990 encourages voluntary source reduction of pollution and waste. Perhaps, this set the stage for more focus on environmental compliance strategizing by businesses and industries.

 

    

 

 

 

Monday, January 6, 2025

Utica Condensate/Light Oil Production Grows in Ohio as the Volatile Oil Window is Drilled in New Ways and Stimulated with New Frac Recipes: Economics Can Be as Good as the Best Permian Wells


     RBN Energy’s Housley Carr wrote an interesting blog post about Ohio’s growing light oil/condensate production in the Utica-Point Pleasant Shale. Carr first notes that the superlight crude being produced from the Utica is better described as condensate. This condensate is valued less than WTI crude. Carr notes regarding the light oil:

“…almost all of it condensate with an API value (or viscosity) of 55 to 59 degrees. More recently, at least a couple of E&Ps in the Utica have been producing small volumes of “heavy condensate” with an API value of 49 to 52-degrees — still far lighter than West Texas Intermediate (WTI), which has an API of about 40 degrees.”






     Well results have improved for a number of reasons, discussed below. Encino, now known here as EAP Ohio, and EOG Resources both describe the Utica volatile oil window as one of the most economic plays in North America.






EAP Ohio has said it is now routinely developing wells with initial production (IP) rates of more than 1.5 Mb/d and often exceeding that mark.”






EOG is getting IPs exceeding EAP’s rates by a little, as the graphic below from their 3Q Earnings presentation shows.






     Carr noted that future blog posts will explore the other producers in the play, including EOG, and

“…examine the possibility that two grades of Utica condensate will emerge, each with their own prices: “regular” condensate with an average API of 58 degrees and heavy condensate with an average API of 52 degrees (and a range of 48 to 54 degrees)

      The number 2 oil/condensate producer Ascent Resources also touts the Utica and their advantages in the play, emphasizing the 'front-end loaded' production resulting in faster payout.








     Expand Energy, the combined company of Chesapeake Energy and Southwest Energy still retains significant Utica acreage as shown below.





     Some maps of drilling depths, geology, and wells drilled are shown below.












     Dave Boyer of Mudrock Energy did some very good analysis of Utica gas and oil production in a March 2022 slide show that better defined the liquids corridors/fairways comparing gas BTU, gas-oil ratios, and API gravity to well production. he also did some interesting comparisons of Marcellus and Utica hydrocarbon fairways. 











Drilling with Water Based Mud (WBM)

     In April 2021 SLB published a case history with drilling two Artex Oil wells, one in Muskingum County and one in Noble County, both in the Utica oil window. Both of these wells are now owned by EOG. These wells were drilled with SLB’s water-based mud system known as HydraGlyde. Their datasheet claims ROPs comparable to oil-based mud, exceptional hole cleaning, and wellbore stability. According to the datasheet:

By providing a high degree of lubricity, the HydraGlyde system overcomes the typical drilling-related problems encountered in more mature shales, such as gumbo accretion in the surface hole, wellbore instability, mud losses in the intermediate section, and solids buildup. The HydraGlyde system is engineered with three components:

 HydraHib™ shale inhibitor, providing a high degree of wellbore stability and exibility with the ability to adjust its concentration

 ‘HydraCap™ encapsulating additive, replacing the conventional partially hydrolyzed polyacrylamide (PHPA) additive to minimize clay dispersion and enhance wellbore integrity

“HydraSpeed™ ROP-enhancing primary lubricant, demonstrating a coefficient of friction factor of 30.8 compared to 39.8 for a higher cost lubricant.”

“The HydraGlyde system replaces oil-based drilling fluids as well as conventional water-based fluids”

It utilizes HydraSpeed, an ROP-enhancing lubricant that reduces torque and drag on the drill string. It also utilizes SLB’s RheoProfiler, an automated drilling mud rheology in combination with their Drilling Fluid Advisor.

Drilling Fluid Advisor makes real-time measurements, increasing operational versatility. RheoProfiler* 200 automated rheometer automates data upload, making accurate and frequent adjustments to rheology and density measured at multiple temperatures. A plug-and-play attachment to the RheoProfiler 200 rheometer takes measurements including pH, oil/water ratio, solids content, and electrical stability and digitally transmits the data to a cloud environment. You can customize an electronic drilling recorder display measurement dashboard and alarms and export data.”

 










Encino Energy’s No-Gel Slick Water Utica Fracs

     Encino Energy acquired Chesapeake Energy’s Utica assets in 2018. Later they focused more on the development of the volatile oil window with bigger pads, longer wells, more precise zone targeting, and new frac designs. EOG has done the same beginning in 2022. Encino is Ohio’s biggest oil producer by far as shown below. As reported in a January 2024 article in American Oil & Gas Reporter:

As the top Utica oil producer, Encino has completed some of the best oil wells in Ohio’s history, and its Utica wells have typical 30-day initial productivities ranging between 1,000 and 2,500 bbl/d.”

Since assuming the position and embarking on its own development program, Encino has boosted liquids production by nearly 35% to 70,000 bbl/d, with about one-third of that being crude oil, Murchison points out. Liquids now account for 40% of Encino’s total daily production of 1.1 billion cubic feet of gas equivalent, he adds.”

Encino is focusing almost all of its current effort in the oil window but can opt to gas if prices change.

The company deploys slickwater fracs and avoids gel in its completions, says Chief Technical Officer Tim Parker. Oil in the Utica comes with a big advantage: After frac water flowback, the wells may produce only a couple of barrels of water a day, he adds. That is a major differentiator with favorable operating expense implications compared with, say, the Delaware Basin, where wells can produce eight barrels or more of water for every one barrel of oil.”

 

 

 

EOG’s New Frac Design

    In May 2023 EOG COO Lloyd Helms Jr. noted: “drilling performance of recent wells is improving on the order of 20% to 30% compared to last year’s results” and attributed the improvements to a proprietary drilling motor program and precision targeting. I wrote a post about the Utica Oil Window in September 2023. I summarized what is known about EOG’s new frac design when it was first revealed in July 2023 in a blog post about enhancing oil & gas production. Here is what I wrote about the design:


EOG’s New Stealth Frac Design: What’s the Recipe?

     EOG recently announced success with a new frac design that increased production in the Permian Wolfcamp formation by 20% and well EURs by 22%. Analysts tried to get them to divulge the recipe with no luck. They had been testing the technique since first using a version of it in the Eagle Ford in 2016. The design was tested in 39 Wolfcamp wells and EOG expects to use it in about 70 of 350 Delaware Basin wells this year. They noted that it works better in some rocks than in others, although they are now using it in the Eagle Ford as well. Indications are that it is only slightly more expensive. They are testing the design cautiously in deep formations and plan to test it in all their emerging plays. It is most applicable to deeper targets, but they plan to test some shallower targets as well. EOG president Billy Helms noted that depending on the mechanics of the rock it’s being applied to, “it involves constructing the wellbore in a way that lends itself to this new technique.” It has also been said that it is applicable to both oil and gas plays.

I bolded Helms’ curious statement. I have not heard any more about it except that some think ammonia is involved in the recipe. I also heard they were using it in the Utica. In EOG's 3Q 2023 Earnings Presentation they showed this graph of improved production in the condensate/oil window.





 

Other Completion Considerations

     The following slide from a Strata Gen would apply more to the deeper gas window Utica and other deep high-pressure shale plays like the Haynesville, where the use of ceramic proppants is common since as the slide notes “sand crushes at 4000 to 6000 psi.”

 






Managed Pressure Drilling Becomes Common in Utica by 2016

     As reported by Weatherford in Hart Energy in 2016, managed pressure drilling (MPD) emerged as the preferred method of drilling. This is often done to prevent mud loss or to prevent gas kicks when encountering pressurized fractures. In the Utica some of these pressurized fractures may result from connection to larger dolomitized Trenton Limestone fractures reaching up from below. The article defined MPD as

“…a closed-loop drilling technique that enables the driller to monitor wellbore pressure profiles and rely on the system to automatically adjust surface backpressure as needed throughout the operation. The approach, which has been applied in land and offshore wells worldwide, is increasingly being adopted by operators to drill gas wells in the diverse Utica Shale, stretching across areas of Ohio, Pennsylvania and West Virginia.”

The usual MPD strategy is to employ constant bottomhole pressure (CBHP) as the optimal solution. These systems are able to detect both gas kicks and mud losses very early in their occurrences, enabling timely parameter adjustments.

“BHP is automatically adjusted by closing the hydraulic chokes to increase surface backpressure, minimizing the size of the kick that must be circulated out without shutting in the well. It automatically reduces surface backpressure to minimize formation damage if the system detects a loss.”

An important enabler of the technology is the rotating control device (RCD), which is installed above the rig’s BOP stack to contain and divert annulus fluids at surface, a critically important and demanding task in MPD operations. Several RCD models are available, each touting different pressure ratings to accommodate a wide range of wells with varying pressure profiles. Compatible with various drilling techniques, including MPD, the RCD diverts well effluent through a dedicated choke manifold. The process ensures that HSE issues are avoided during the drilling operation.”

"The overall drilling strategy for all the wells was to mitigate potential problems related to kicks and losses by keeping the equivalent circulating density steady—above the estimated pore pressure and below the estimated fracture pressure—during dynamic and static conditions. Operators also wanted the ability to detect early kicks and losses; this was achieved by measuring return volumetric rates and adjusting bottomhole conditions instantly using the MPD choke to limit influx volumes when natural high-pressure fractures were crossed."

     One method of CBHP MPD drilling is Pressurized Mudcap Drilling (PMCD). According to Petrowiki:

Pressurized Mudcap Drilling (PMCD) refers to drilling with no returns to surface where an annulus fluid column, assisted by surface pressure, is maintained above a formation that is capable of accepting fluid and cuttings. The well is controlled by using a Light Annular Mud (LAM) that has a slightly lower density than is required to balance the formation pressure and is maintained above an open-hole formation that is taking all injected sacrificial (SAC) fluid and drilled cuttings assisted by surface pressure. The LAM density is chosen based on ability to make LAM and the desired surface pressure that can be maintained and observed. Periodically injecting more of the same fluid into the annulus provides a means to control the surface backpressure within the operating limits of the Rotating Control Device (RCD) and/or riser system. The annular fluid is injected at a rate high enough to ensure that gas is not migrating up the annulus. The injection rate and associated annular velocity are designed to stop gas migration to surface and to force any formation gas back into the well – effectively bullheading the gas back into the formation. [4].”

Pressurized Mud-Cap Drilling is a time-tested technique to safely penetrate the formations difficult or impractical to drill with other methods. PMCD is widely used in fractured or carbonate reservoirs that experience total fluid losses. Large volumes of sacrificial fluid are required and specialized rig modifications are minimal for PMCD operations. PMCD allows to keep dangerous gasses like H2S downhole, thus considerably enhancing the safety of the project.”







I have worked on wells in the Austin Chalk in South Texas where drilling on ‘mudcap’ was common.

     Another method long used in the Appalachian Basin is drilling the top hole or vertical part of the hole with compressed air to remove cuttings. This results in a faster ROP. In some cases, even part of the build can be drilled on air but I am not sure how common this is nowadays.

 

 

References:

 

Hit the Lights - Condensate Production Takes Off in Eastern Ohio's Utica Shale. Housley Carr. RBN Energy, LLC. January 3, 2025. Hit the Lights - Condensate Production Takes Off in Eastern Ohio's Utica Shale | RBN Energy

3Q 2024 Earnings Presentation. EOG Resources. *Earnings Presentation

3Q 2024 Earnings. Expand Energy. October 29, 2024. EXE_3Q24_Earnings_Presentation.pdf

Case Study: Artex Energy Group Drills Two Wells in Zone Using High- Performance Water-Based Drilling Fluid, Utica Formation. SLB. April 5, 2021. Artex Energy Group Drills Two Wells in Zone Using High- Performance Water-Based Drilling Fluid, Utica Formation | SLB

HydraGlyde: High-performance water-based drilling fluid system. SLB. hydraglyde_data_sheet.pdf

HydraSpeed: ROP-enhancing primary lubricant. SLB. HydraSpeed ROP-Enhancing Primary Lubricant

RheoProfiler: Automated rheometer. SLB. RheoProfiler system tests all mud types | SLB

Drilling Fluid Advisor: Digitize Your Drilling Fluids. SLB. Drilling Fluid Advisor

Refined Drill Bit Technology for Underbalanced Drilling in the Northeast United States. Aaron J. Goodman; Robert E. Grimes; Christopher W. Lane. Paper presented at the SPE Eastern Regional Meeting, Charleston, West Virginia, USA, October 2019. Refined Drill Bit Technology for Underbalanced Drilling in the Northeast United States | SPE Eastern Regional Meeting | OnePetro

Drilling the Point Pleasant-Utica Shale Fractured Formation During the COVID-19 Pandemic Utilizing CBHP MPD with a PMCD Contingency. Sagar Nauduri; Ahmed Shimi; Gildas Guefack; Martyn Parker. Paper presented at the IADC/SPE Managed Pressure Drilling & Underbalanced Operations Conference & Exhibition, Virtual, September 2021. Drilling the Point Pleasant-Utica Shale Fractured Formation During the COVID-19 Pandemic Utilizing CBHP MPD with a PMCD Contingency | SPE/IADC Managed Pressure Drilling and Underbalanced Operations Conference and Exhibition | OnePetro

Managed pressure drilling. PeteroWiki. Managed pressure drilling - PetroWiki

Encino Leads New Era Of Utica Shale Development Targeting Oil Window. Danny Boyd. American Oil & Gas Reporter. January 2024. Encino Leads New Era Of Utica Shale Development Targeting Oil Window | Editors Choice | Magazine

Engineering World Class Wells in the Utica. Brian Davidson. Technical Manager, StrataGen, a CARBO Business. November 2024. Main presentation title

Encino’s Tim Parker: Plenty of Utica Oil—and Takeaway Too. Hart Energy. November 15, 2024. Encino’s Tim Parker: Plenty of Utica Oil—and Takeaway Too | Hart Energy

EOG Resources: Continued Growth and The Utica Shale. Brent Hecht. Seeking Alpha. January 16, 2024. EOG Resources: Continued Growth And The Utica Shale (NYSE:EOG) | Seeking Alpha

EOG to ramp Ohio Utica activity by 50% next year. Geert De Lombaerde. Oil & Gas Journal. November 8, 2024. EOG to ramp Ohio Utica activity by 50% next year | Oil & Gas Journal

Column: EOG on Its New Frac Design: ‘No Comment. Nissa Darbonne. Hart Energy. July 17, 2023. Column: EOG on Its New Frac Design: ‘No Comment’ | Hart Energy

MPD Emerging As Preferred Drilling Method In Utica Shale: Technology improves efficiency and reduces NPT. Hunter Craig, Juan Valecillos, Maurizio Arnone and Roy Callison, Weatherford. Hart Energy. November 10, 2016. MPD Emerging As Preferred Drilling Method In Utica Shale | Hart Energy

Utica Oil Activity. Dave Boyer. Mudrock Energy. March 2022. Utica-Oil-Mudrock-2022.pdf

 

 

Saturday, January 4, 2025

U.S. Crude Oil Imports from Canada at Record Highs from Expansion of Trans Mountain Pipeline and U.S. Oil Trade Graphs


     In May 2024 Canada’s Trans Mountain Pipeline completed its expansion from 300,000 Bbls of oil/day capacity to 890,000 Bbl/day capacity. U.S. crude oil imports from Canada reached a record of 4.3 million barrels per day (Bbl/d) in July 2024 following the expansion of Canada’s Trans Mountain pipeline. As indicated in the second graph below U.S. West Coast refineries as well as Asian importers bought most of the new volumes coming from Alberta to the Pacific coast.

The U.S. West Coast imported 498,000 b/d of crude oil in July 2024, according to our PSM, a record high for the region and an increase of 115% compared with July 2023.”

 







     Western Canada Select (WSC) is sold at a significant discount to Brent oil due to its lower quality in the form of higher sulfur content and lower API gravity. In addition to that the oil source is landlocked due to geography and must be pumped via pipeline a long way to sales, either on the Pacific coast, to U.S. Midwest refiners, or to the U.S. Gulf Coast. The price differential is significant, sometimes over $20. The price differential is also seasonal as Midwest U.S. refineries shut down in the fall for maintenance. There is some indication that the differential has dropped as the connection to the Pacific coast has given Canadian producers some optionality to cushion the seasonal loss of sales volumes due to Midwest refinery maintenance.  





     Trump’s predilection to rule by threat, intimidation, and unpredictability, recently shown by his threat of 25% tariffs on Canadian goods, would be painful to both Canada and the U.S. Of course, it is unlikely to happen. The U.S. relies on Canadian crude oil. Canada is by far our biggest foreign oil supplier, most of which can be which can be delivered by pipeline to U.S. refineries, which are outfitted to process it. It is nice that we can get so much of our oil imports from a nearby and friendly country with few geopolitical risks. Trump seems mostly concerned with attaining trade balances with friendly countries like Canada and the E.U. It is perhaps a valid point to question why we are buying more than we are selling. Trump wants the E.U. to buy more U.S. oil & gas to reduce the deficit. In addition, the EU now requires that the oil and gas they buy has some level of verifiable compliance with environmental best practices and labor laws. U.S. oil & gas meet those requirements better than other sources. However, the E.U. as a whole and their individual countries also have to consider their own economic situation in that their cost to import LNG is significantly higher than the cost of pipelining it from Russia or anywhere else.

     In October 2024 the U.S. got 58.3% of its oil imports from Canada. Imports account for about 40% of U.S. oil and petroleum products consumption. That means that about 23.2% of the oil we consume in the U.S. comes from Canada. It also means that about 83% of the oil consumed in the U.S. comes from either the U.S or Canada.

     The U.S. is since 2020 a net exporter of crude oil. That gives us a positive trade balance metric as well as improving our energy security by sourcing more crude domestically.






     As can be seen below U.S. oil imports peaked in 2005, dropped, had another small peak during Trump’s first term, dropped to all-time lows during the pandemic, and have risen a bit since then.

 



        Crude oil imports to the United States in selected years from 2000 to 2023 (in million barrels)

 


 Source: Statista

 

 

             Total petroleum exports from the United States in selected         years from 1950 to 2023 (in 1,000 barrels per day)


 Source: Statista




References:

 

Crude oil imports from Canada reached a record after pipeline expansion. EIA. Today in Energy. October 30, 2024. Crude oil imports from Canada reached a record after pipeline expansion - U.S. Energy Information Administration (EIA)

Petroleum and Other Liquids: U.S. Imports by Country of Origin. EIA. U.S. Total Crude Oil and Products Imports

US Oil Imports Data by Country, Top US Oil Importers & Buyers List. U.S. Import Data. November 23, 2024. US Oil Imports Data by Country, Top US Oil Importers & Buyers List - USImportData - US Import Export Data

 

Friday, January 3, 2025

U.S. Energy Production Continues to Exceed Consumption, A Milestone First Hit in 2019: Growth of Domestic Oil and Natural Gas Production Due to Fracking Allows Coal Use to Drop


     Since 2019 the U.S. has produced more energy than it consumes. It has done this while cutting energy production from coal by half since coal production peaked in 2008. How were we able to do this? Largely due to fracking. Energy efficiency and growth in wind and solar helped but increases in domestic oil and gas output are by far the main factor. The 2019 milestone was important since the U.S. had last produced more energy than it consumed way back in the 1950s. spread between production and consumption has grown to a record high in 2023. EIA explains its methodology and the results below:

To compare different types of energy reported in different types of physical units (such as barrels, cubic feet, tons, and kilowatthours), we convert sources of energy to common units of heat called British thermal units (Btu). Noncombustible renewable sources such as hydroelectric and solar energy are converted to Btu using the constant conversion of 3,412 Btu per kilowatthour.”

The increase in total U.S. energy production was driven largely by growth in the production of natural gas and crude oil in 2023. Dry natural gas production grew 4% to a record 39 quads in 2023, growing 58% since 2013. Crude oil production grew 9% from 2022 and reached a record of 27 quads in 2023, a 69% increase since 2013. Production of natural gas plant liquids, a byproduct of natural gas production, increased by 8% from 2022 to 8 quads in 2023. Natural gas plant liquids production has increased by 143% since 2013.”

Energy production from renewable sources increased 1% from 2022 to a record 8 quads in 2023, a 28% increase since 2013. Solar energy production grew by 15% last year, reaching almost 1 quad, and biomass energy production grew nearly 2% to more than 5 quads. Wind production fell last year by 2% to about 1.5 quads, with wind speeds slower last year.”


The graphs below clearly show the positive results of domestic oil and gas production for replacing coal, thereby lowering carbon emissions, air pollution, and potential water pollution very significantly.

 














     Some other interesting observations from these graphs reveal some interesting facts. Firstly, natural gas plant liquids such as ethane, propane, butane, and isobutane produce as much energy as all renewables combined. Secondly, and this is very important to note, biomass in the form of wood, waste, and biofuels combustion resulted in 60% of the total renewables production (see 2nd graph). Solar consumption represents just 11% of total renewables consumption and wind consumption represents just 17% of total renewables consumption. Thus, 27% of total renewables consumption came from wind and solar. We consumed double the amount of energy from burning wood alone than we did from solar and about the same amount of energy from wood and waste combined as from wind and solar combined. Clearly, the energy transition remains very challenging and unrealistic in the near term.

 


Data Source: EIA




Data Source: EIA



     Wind generation actually declined in 2023 for the first time since the 1990s. One reason was slower wind speeds. Wind capacity factors have increased modestly since 2010 from about 30% to about 34% but have remained pretty flat since 2013.

 

 


 






References:

 

U.S. energy production exceeded consumption by record amount in 2023. Energy Information Administration. Today in Energy. June 26, 2024 (Re-published December 31, 2024). U.S. energy production exceeded consumption by record amount in 2023 - U.S. Energy Information Administration (EIA)

Table 10.1 Renewable Energy Production and Consumption by Source. EIA. Microsoft Word - MER_S10

Wind generation declined in 2023 for the first time since the 1990s. EIA. April 30, 2024. Wind generation declined in 2023 for the first time since the 1990s - U.S. Energy Information Administration (EIA)

Range Resources: Company Presentation. October 2024. PowerPoint Presentation

  As the title of this post points out, the U.S., China, and the EU countries make up about two-thirds of UN funding in a normal year. The...