COVERING THE ENERGY INDUSTRY IN THE ROCKY MOUNTAIN REGION
BIG DATA SOLUTION
Colorado millennial earns patent for time-saving information filter SPACING UNIT CRUNCH
MANDATE CHANGE?
MIGRATION INFLATION
Regulators see growth in competition among operators
State appellate court, State’s COGCC errs in interpretation of its directive
Oil, gas migration boosts Weld County population
MAY 2017 | VOL 4 | ISSUE 9
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Features
Colorado Millennial earns patent for time-saving information filter SPACING UNIT CRUNCH
MANDATE CHANGE?
MIGRATION INFLATION
Regulators see growth in competition among operators
State’s COGCC errs in interpretation of its directive
Oil, gas migration boosts Weld County population
MAY 2017 | VOL 4 | ISSUE 9
12 MIGRATION INFLATION
14 BIG DATA SOLUTION
Colorado millennial earns patent with time-saving information filter
Oil, gas migration boosts Weld County population Sharon Dunn
18
MAKING HOLE
20
TECH TALK
The first North Dakota oil well Bruce Wells
Matthew Van Deventer
8
SPACING UNIT CRUNCH
Regulators see growth in competition among operators Dan Larson
Smart controller increases efficiency and lowers costs of small solar power systems Gary Beers
10
MANDATE CHANGE?
State appellate court says COGCC errs in interpretation of its directive Sharon Dunn
4 ENERGY PIPELINE MAY 2017
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Colorado regulators face increasing protests and objections as operators compete for best spacing units BY DAN LARSON FOR ENERGY PIPELINE
As companies survey the landscape for new oil and natural gas wells in Weld County and across the Denver-Julesburg Basin, their plans often call for horizontal wells extending one or two miles in every direction. Sometimes, their plans compete for the same underground acreage as other operators. Tasked with resolving these disputes, the Colorado Oil & Gas Conservation Commission was provided an update on the issue at its January hearing but stopped short of revising its rules, according to Matt Lepore, the commission’s executive director. Commission staff “does not believe a rulemaking is necessary at this time, but if operators are not willing to provide relevant information (during review of competing requests), commissioners may need to revisit the issue,” Lepore said. The issue of competing requests can arise when a company submits plans to drill a new well. Colorado rules state the well must be drilled within the boundaries of an existing spacing unit or in a newly created unit. Once a spacing unit is established, all mineral holders, whether owner or lessee, within that unit are granted a proportional share of the well’s production, less taxes and fees charged by the operator. Oil wells in the DJ have gotten longer and cross more mineral tracts while fewer undeveloped, productive areas remain. As a result, companies can find themselves competing for the same undeveloped acreage with other operators. Spacing Competition Competing spacing unit requests are not a new issue for Colorado regulators. The
traditional means of determining who is awarded the unit, and as a result, the right to drill and operate the well goes to the first to file a request. However, on occasion a second operator will file a spacing unit request for the same acreage. Commission staff then reviews the competing requests, considers the merits of each and awards the unit to the operator who can clearly show a better proposal. The process involves meetings with the operators and any mineral holders who may have an objection. Among the factors that can move the needle in favor one side or the other, are plans that integrate infrastructure such as pipelines to reduce impact on neighbors,
WATTENBERG FIELD DRILLING & SPACING UNITS ESTABLISHED, 2014-2016
0
0
1920 acre
0
1
0
1280 acre
17
10
19
640 acre
21
5
10
320 acre
5
5
4
Misc.
1
4
7
44
25
41
Total new drilling units
1
Source: COGCC
HORIZONTAL WELLBORE SPACING ESTABLISHED, 2014-2016
2014 2015 2016
More than 720 acre
15
18
41
Less than 720 acre
58
67
106
Less than 640 acre
182
213
266
Less than 480 acre
389
365
252
Less than 320 acre
638
469
303
Less than 160 acre
98
73
55
Total new wellbore units Source: COGCC
8 ENERGY PIPELINE MAY 2017
2014 2015 2016
2560 acre
1380 1205 1023
plans that better protect the correlative rights of mineral holders, and plans that do not strand minerals or cause them to be wasted. Objections to spacing unit requests can be filed by mineral owners who may contend their resource would be wasted, their correlative rights to the resource are diminished, or that the operator does not actually control the minerals. According to director Lepore, commission staff has seen an increase in the number of objections and protests to spacing unit requests but “due to a staff review and involvement in pre-hearing conferences, most are eventually resolved” before going before the board. For competing requests that are too close to call, the staff will recommend the spacing unit go to the first to file, he said. “Historically, first-in-time is our tiebreaker,” Lepore noted. “Although it is a long-standing practice, it is not a statutory or regulatory requirement.” Wellbore Rules For undeveloped mineral acreage not in a spacing unit, state rules allow an operator to create a wellbore spacing unit for a single well; otherwise, the operator requests a drilling-and-spacing unit for one or more proposed wells. Under COGCC rule 318A, when an operator plans to drill a horizontal well, all the quarter-quarter sections, basically a 40-acre tract, and all adjoining quarterquarter sections that are within 460 feet of the proposed wellbore, are included in the spacing unit. The company submits the proposed wellbore spacing unit along with their regular drilling permit application on
COGCC Form 2 and a location assessment package under Form 2A. If, within the 30-day comment period, there are no objections, the wellbore spacing unit can be approved administratively by the director along with the drilling permit applications. If, however, the company plans multiple wells from one or more wellsites, it is required to file a request to establish a drilling and spacing unit before filing a drilling application. The request is then set for hearing by the commissioners. Board-approved drilling and spacing units are the traditional avenue to forming a spacing unit; wellbore spacing units are a fairly new concept and do not require board approval. Wellbore spacing units provide operators with greater flexibility while maintaining the right to object for mineral owners. They are generally issued to the first operator to file, according to Jane Stanczyk, permit manager at COGCC. “You can’t have two wells in the same place,” Stanczyk said. “Sometimes it’s a race to see who can file the first permit. If a second application for the same acreage comes in later, we have to deny it.” According to COGCC, the majority of wells drilled over the past three years were
within wellbore spacing units. Records show that during 2014-16, wells drilled in drilling and spacing units, either new or already established, totaled 1,549, while wells drilled in wellbore units totaled 3,608. Last year, protests filed against either drilling or wellbore units were less than 1 in 50; efforts to resolve objections through meetings were largely successful, according to commission records, as only four protests went before the board. Spacing Background Colorado established spacing rules for wells drilled into the Niobrara formation in 1992. At the time, nearly all wells drilled were vertical and spacing units were set at 80 acres, with two wells allowed per unit. It was at that time the 460-feet from the wellbore rule was established. Six years later, the rule was revised to allow addition of a fifth well within each 160acre quarter-section. The spacing unit for these “five-spot wells” overlaid any existing 80-acre units. This arrangement covered wells drilled in what the COGCC describes as the Greater Wattenberg area. With the arrival of horizontal wells in the last decade, the rules were again revised to allow for infill and boundary units of up to 160-acres. It was in this rule revision,
enacted in 2005, the commission established rules for wellbore spacing units. These rules required sending notice to and a 30-day comment period for mineral owners and allowed staff-approval of spacing units in conjunction with drilling permits. Once established, wellbore spacing units can be pooled with other units, according to Rule 318A. In 2011, as companies were requesting permits for longer lateral wells, wellbore spacing unit rules were expanded to specifically include horizontal wells. This allowed operators greater flexibility to describe spacing units that increased oil and gas production while considering preferred wellsite locations with respect to neighbor concerns. The commission was careful to protect the right to object for mineral owners within a proposed spacing unit and to allow operators to plan wells that reduce surface impacts, director Lepore said. “If there are objections, the operator works with the mineral owner to resolve them. If the conflict cannot be resolved, either the operator or the owner can request their concerns be heard by the commissioners,” he observed.
MAY 2017 ENERGY PIPELINE 9
State appellate court rules COGCC errs in interpretation of state mandate BY SHARON DUNN • SDUNN@ENERGYPIPELINE.COM
The Colorado Court of Appeals in March dealt a bit of a blow to the state’s oil and gas regulation arm, stating the agency is misinterpreting its mandate when regulating oil and gas — a ruling that the former agency director believes may spawn more challenges to its decisions. The ruling — which states the COGCC’s mandate is to regulate oil and gas conditional upon the public health safety and welfare — comes in the case of six Colorado children who sued the Colorado Oil and Gas Conservation Commission two years ago in their quest to create a rule halting all new oil and gas development in the state until it could be proven the practice was safe. The six youths, representing the Boulderbased group Earth Guardians, had sought a rule-making from the commission in 2013. The COGCC rejected it because it stated it didn’t have the authority under its mandate from the state, which officials believed required them to find a balance between the needs of oil and gas development and public safety. The children appealed, and the court sided with them in a 2-1 decision in March. “We … conclude that the commission erred in interpreting (their legislative mandate) as requiring a balance … “ the court ruled. “The plain meaning of the statutory language indicates that fostering balanced, nonwasteful development is in the public interest when that development is completed subject to the protection of public health, safety and welfare ... including protection of the environment and wildlife resources.”
10 ENERGY PIPELINE MAY 2017
The ruling was predictably met with disagreement and disappointment among those in the industry. Tracee Bentley, executive director of the Colorado Petroleum Council, issued the following statement: “We are disappointed with today’s split decision, which we believe is without sound legal basis. The Colorado oil and natural gas industry’s long record of environmental stewardship belies the need for additional onerous rules and restrictions. This sweeping decision imperils jobs, incomes,
WE MAY SEE MORE CHALLENGES TO AGENCY DECISIONS ON THE GROUNDS THAT THE AGENCY DECISIONS ARE INCONSISTENT WITH THIS MANDATE THAT THE COURT OF APPEALS HAS FOUND. DAVE NESLIN, the former director of the COGCC, and a practicing attorney in Denver and development of natural resources in our state.” The ruling on its face doesn’t automatically mean the children will get their wish, however. They can resubmit their request to create a new rule to the commission, which is not bound by the appellate court ruling to do so. The ruling simply means the commission cannot reject such a request because they don’t have the authority. But it may have deeper, maybe more far-reaching consequences. Dave Neslin, the former director of the COGCC, and
a practicing attorney in Denver, predicted this ruling may result in some legal challenges to the COGCC’s decisions going forward and open a door to a labyrinth of interpretations. “The issue that this raises is what does protection of public health, safety and welfare mean in this context?” Neslin said. “That provision is addressing how clean is clean. It’s saying, now the standard isn’t to the maximum extent that’s humanly possible. The standard is to mitigate significant adverse impacts in a manner that takes into consideration” health safety and welfare, Neslin said. “We may see more challenges to agency decisions on the grounds that the agency decisions are inconsistent with this mandate that the court of appeals has found.” What’s more, the decision could put the onus of decision making in oil and gas matters on the courts. “It could ultimately shift some decision-making from the agency to the courts, in wrestling with what is protecting the environment mean,” Neslin said. The Oil and Gas Conservation Act originally stated, “It is hereby declared to the be in the public interest to foster, encourage and promote the development, production and utilization of the natural resources of oil and gas in the state of Colorado.” The language about protecting public health and welfare was added to existing statute in 1994. The wording was again changed in 2007 to add that it is in the public interest to development the state’s resources. “These amendment reflect the General Assembly’s general movement away from unfettered oil and gas production and incorporation of public health safety, and
LEGISLATIVE INTENT OF THE OIL AND GAS CONSERVATION ACT “It is declared to be in the public interest to foster the responsible, balanced development, production, and utilization of the natural resources of oil and gas in the state of Colorado in a manner consistent with protection of public health, safety, and welfare, including protection of the environment and wildlife resources (§34-60-102(1)(a)(I));…plan and manage oil and gas operations in a manner that balances development with wildlife conservation in recognition of the state’s obligation to protect wildlife resources and the hunting, fishing, and recreation traditions they support, which are an important part of Colorado’s economy and culture.” (§34-60-102(1)(a)(IV)) “It is not the intent nor the purpose of this article to require or permit the proration or distribution of the production of the oil and gas among the fields and pools of Colorado on the basis of market demand. It is the intent and purpose of this article to permit each oil and gas pool in Colorado to produce up to its maximum efficient rate of production, subject to the prevention of waste, consistent with the protection of public health, safety, and welfare, including the protection of the environment and wildlife resources…” (§34-60-102(1)(b) §34-60-106 – The COGCC has the authority to regulate “Oil and gas operations so as to prevent and mitigate significant adverse environmental impacts on any air, water, soil, or biological resource resulting from oil and gas operations to the extent necessary to protect public health, safety, and welfare, including protection of the environment and wildlife resources, taking into consideration cost-effectiveness and technical feasibility.” (§34-60-106(2)(d))”
welfare as a check on that development,” the ruling stated. “This understanding supports our conclusion that the act was not intended to require that a balancing test be applied when agencies charged with carrying out and enforcing the intent behind the act.” Neslin said the COGCC has created pages and pages of rules in keeping with environmental protection, and many rulemakings in the last several years have tightened
restrictions on the oil and gas industry in keeping with its mandate to protect the health and safety of the public, and protect the environment. “I suspect all the oil and gas commission staff and commissioners believe they are already protecting the public health, safety and welfare, and can point to hundreds of pages of regulations, policies and instructions that require specific actions to protect public health, safety and welfare. Another
reading of this would be that it doesn’t really require much more than what the commission is already doing.” Neslin said he would expect the COGCC to appeal the ruling to the Colorado Supreme Court. In its own statement, the COGGC said it had not yet decided whether to appeal the ruling. “We are evaluating whether to appeal this decision to the Colorado Supreme Court.”
MAY 2017 ENERGY PIPELINE 11
OIL AND GAS MIGRATIONS HELPS
BOOST
POPULATION
IN WELD COUNTY
BY SHARON DUNN: SDUNN@ENERGYPIPELINE.COM
I
f you thought Weld County was awash in big trucks and a growing herd of oil field workers, that may not be far from the truth. The county was listed in March as the fourth fastest-growing metropolitan statistical area in the United States, gaining population at a 3.5 percent clip from July 1, 2015, to July 1, 2016, while other oil-rich areas along the Rocky Mountain West lost population in that time. Oil field workers tend to migrate where the work is, but it’s not often documented. While the phenomenon of the traveling oil and gas fleets is more anecdotal, there could be some truth in it fueling Weld’s population. “I was just out on the Western Slope. When I’m in Montrose County or Mesa, people often talk about when their economy started to suffer, all the people were migrating to North Dakota to work in oil fields or as contractors out there,” said Brian Lewandowski, associate director of the Business Research division of the University of Colorado’s Leeds School of Business. “We know that the phenomenon happens, but it’s hard to say your gain is Wyoming’s loss.” In the 12-month period, the U.S. Census estimated Weld’s population grew by 9,879
12 ENERGY PIPELINE MAY 2017
people – that includes 4,106 births and 1,725 deaths. State demographers blame the bulk of the growth on migration; indeed, Weld saw its numbers swell by 7,300 in the study period, 6,991 of which were domestic migrations, and 390 more that were international, according to the U.S. Census bureau. Just looking at population changes among the region’s larger oil fields, their losses may indeed have become Weld’s gain. Together, four oil-and-gas-rich metro areas in Wyoming, North Dakota and Utah lost 4,284 people in the same time that Weld gained. Other oil areas in Texas also saw big population losses, but other oil areas down south grew substantially in that time and likely absorbed those losses. Official numbers on job growth in the oil and gas industry have not yet mirrored the population growth, but that is likely about to change. Since the beginning of the year, Weld’s job picture began looking up — dramatically. The number of oil and gas related jobs offered through Employment Services of Weld County has already spiked. In the first quarter of the year, there were 166 jobs in the field up for grabs, compared to just 51 at the same time last year, said Lora Lawrence, business services manager for Employment Services of Weld County. Likewise, oil and gas employers make up a good third of the twice-monthly job fairs through the agency.
“It is encouraging as far as the energy sector as a whole,” Lawrence said. “Without a doubt we have certainly seen an increase in oil and gas employers signing up for onsite job fairs. We have two per month, and we have seen 15 employers in the first quarter. That is a significant increase over this time last year – at least double.” Lawrence said the agency is looking to create a larger job fair in June to accommodate the growing number of oil and gas employers looking. “It really is very exciting to see the response we’re getting from employers right now,” she said. Colorado’s rig count also is growing. Colorado started March with 25 rigs, and ended the month with 30. Wyoming, on the other hand, reduced its rigs by one to 16 from the beginning of the month. Each rig supports about 100 jobs. Meanwhile, surrounding energy states have been losing jobs, Lewandowski said. “Wyoming is still losing jobs, New Mexico is still losing jobs and North Dakota, too,” Lewandowski said. “If you look at the energy intensive economies, they have been losing jobs year over year.” Weld County, Lewandowski said, is buffered by its diversity. Once primarily an agriculture-based county, Weld now has a strong mix of ag, oil and gas, manufacturing and health-related industries, which remained strong even with an oil and gas downturn in the last two years.
POPULATION CHANGES IN OIL-AND-GAS DENSE AREAS
“People didn’t stop moving there, so you were much more buffered on the downside than I expected,” Lewandowski said. “The fact that you’re still growing jobs year over year, that’s really important.” Frankly, said Richard Werner said, CEO and president of Upstate Colorado Economic Development, growth begets growth. “When you have a thriving economy, it produces opportunities,” Werner said. “You have indirect economic benefits as well. So people are coming in with new retail opportunities, new housing opportunities, all of those things because the job market is so strong.” The red flag in the growth, obviously, is the demand and strain it puts on the area’s infrastructure, housing prices and work force. “We’re starting to see more and more congestion on the roads. Housing prices is another concern. For companies, available work force is a concern,” Werner said. Weld is still considered more affordable than other northern Colorado areas, but demand is pushing up prices. The diversity of Weld’s housing options helps attract people here, as well, Werner said. While there is low inventory of available homes for sale, there’s also enough multi-family housing to fill the gaps. Werner said one main concern is educating a work force for the available jobs that come to the area “You need to make sure you’re creating alignment in the educational system, so that the people coming out of the education system are prepared to work jobs that need to be filled,” Werner said. “There’s plenty of available jobs, and plenty of people but no alignment. It’s a problem here and northern Colorado as a whole.”
Area Population Weld County 294,932 Rock Springs, Wyo. 44,165 Casper, Wyo. 81,039 Minot, N.D. 78,723 Vernal, Utah 36,373 Odessa, Texas 157,462 Midland, Texas 168,288 San Antonio, Texas 2,429,609 Corpus Christi, Texas 454,726 Oklahoma City 1,373,211 Source: U.S. Census Bureau
Change + 9,879 (+3.5 percent) -528 (-1.2 percent) -1,152 (1.4 percent) -1,188 (-1.5 percent) -1,416 (-3.7 percent) -2,227 (-1.4 percent) +1,293 (+0.77 percent) +1,293 (+2 percent) +1,991 (+0.44 percent) +16,246 (+1.2 percent)
COLORADO POPULATION CHANGES
The U.S. Census Bureau looked at population changes from July 1, 2015, to July 1, 2016. Weld County was noted as having the fourth fastest-growing population in that time across the country. Here are some significant findings in Colorado’s population growth: Area Population Change Weld County 294,932 + 9,879 people (3.5 percent) Fort Collins 339,993 +6,124 people (1.8 percent) Denver-Aurora-Lakewood 2,853,077 +44,261 people (1.6 percent) Boulder 322,226 + 3,488 people (1.1 percent) Source: U.S. Census Bureau
MAY 2017 ENERGY PIPELINE 13
BIG DATA SOLUTION
Colorado millennial earns patent on time-saving information filter BY MATTHEW VANDEVENTER FOR ENERGY PIPELINE
Broomfield - based PetroDE recently announced a newly patented technology that will help oil and gas companies find exactly what they are looking for quicker and more efficiently. “What this particular patent does is, it’s a way of speeding up the display of data to a user in a way that retains the information hidden within the data,” explains PetroDE’s Senior Software Engineer Dylan Herron who authored the patent. “We’re trying to get that to the user as quickly as possible without removing any of that valuable geolocation information that you might lose with other methods.” PetroDE, a company under Vesmir Inc., claims to be the world’s first petroleum decision engine, providing tools and technologies to the oil and gas industry such as data analysis, aggregation, visualization and collaborative technologies to help companies make more informed decisions out in the field, according to its website. The U.S. is home to millions of oil and gas wells, active and inactive, and each one has its own set of data points. Weld County alone has almost 23,000 active oil and gas wells. If an oil or gas operator is looking to move into an area, they need to understand the surface and underground properties by analyzing an overwhelming amount of well data. Methods used to compile this well data can take a long time and important pieces of the data are usually left out. PetroDE’s patent, titled, Pattern-retaining Method for Displaying Large Volumes of Geographic Based Data Using Statistical Depopulation, provides clients with user-friendly well data that includes key points unique to their needs while not sacrificing timeliness. It’s driven by two algorithms that include density information outlier data. “We’re cutting out parts of the data, but we’re smart in the way of selecting what parts of the data we cut out and not just randomly selecting [what] to cut out,” explains Herron. “... We’re trying to help them answer the question as quickly and efficiently as possible because if they can do that quickly, they can move on to the next question.” The patent isn’t limited to the oil and gas industry and can be used in any geographic representation of data. It could be applied to geolocated data like schools, coffee shops, or businesses. “This patent is really important to us,” says PetroDE CEO, Alan Lindsey. “It’s fundamental to your work because it allows us to present large data sets very rapidly. So we’ve beaten Google to the 14 ENERGY PIPELINE MAY 2017
punch, providing a way for people to visualize large data sets and very quickly.” It’s difficult to calculate exactly how much time the technology saves clients because each one has different needs, according to Lindsey. However, on the PetroDE website, they claim to be able to save 40 percent of meeting time with their services and can display data from 4.7 million wells in just 11 seconds. With Herron’s patent, companies can do a quick search and find the well data they are looking for in an easy-to-use format. For example, they could show a client in real-time all the wells in the Greeley are and pertinent information for them. Before, they might have had to wait a week for maps to be drawn up. Lindsey says other companies, like Google, may have already developed this kind of technology, but it’s not really applicable to consumers because they aren’t looking to categorize 4.7 million Starbucks by color because they want a latte. The oil and gas industry on the other hand is asking the right questions.
US Patent No. 9,594,773 Pattern-retaining Method for Displaying Large Volumes of Geographic Based Data Using Statistical Depopulation. Filed: May 20, 2014
Issued: March 14, 2017
Abstract: “Disclosed herein are various embodiments of a method for graphically displaying large volumes of data points on a display in an intuitive and readily understandable manner using statistical depopulation by defining multiple regionation levels using a combination of location based data and density based data with a random selection process to add more data points as more detail is requested while retaining the same overall pattern as when all points are displayed. Also disclosed are various embodiments for using the geographic bounds of a screen display to determine the appropriate level of data to display. The embodiments described ensure that the user is not overwhelmed by too much data on screen for areas with multiple data points, while ensuring that areas with few data points are also represented on the display.”
Herron, 24 , started as a contract worker with PetroDE when it was getting off the ground and he was attending the University of Colorado - Boulder for electrical engineering. His patent was one part of a larger project Herron has been working on full-time for the past two years that focuses on how to better represent data. “It’s pretty exciting,” says Herron about the patent. “This is the most public-facing contribution I’ve ever made to the field. ... It’s interesting and exciting to realize that something you’re working on is truly unique and something that’s never been done before.”
MAY 2017 ENERGY PIPELINE 15
News Briefs THOUSANDS OF DEFECTS FOUND ON OIL TRAIN ROUTES BILLINGS, Mont. — When a freight train derailed in the Montana town of Culbertson, spilling 27,000 gallons of crude oil, investigators blamed the 2015 accident on defective or missing fasteners used to hold the tracks in place. The previous year, cracks in a track that went unrepaired caused a train hauling oil to come off the rails and explode along the James River in Lynchburg, Va. Broken bolts were cited in another oil train derailment and fire last year in Mosier, Ore. Data obtained by The Associated Press shows that tens of thousands of similar safety defects were found when government inspectors checked the rail lines used to haul volatile crude oil across the country. The defects included rails that were worn, bolts that were broken or loose or missing, and steel bars that had cracks. Such flaws are not uncommon across the nation’s 140,000mile freight rail network. But these nearly 24,000 imperfections drew heightened attention because of a surge in recent years of domestic energy production that has increased rail shipments of oil and the number of major derailments. The inspectors also noted failures by railroads to quickly fix problems identified through inspections. A former senior official at the Federal Railroad Administration said the findings reinforce the need for railroads to stay on top of regular maintenance. “All of this is a call for continued vigilance,” said Steven Ditmeyer, who reviewed the inspection data and directed the railroad administration’s Office of Research and Development for eight years. “One defect or one violation of the right kind can cause a derailment.” It can be difficult for railroads to know when a seemingly small problem will result in an accident, he said. The statistics “give a good indication of the track quality,” Ditmeyer said, although most defects will not cause a derailment. In all, nearly 24,000 defects were found on almost 58,000 miles of oil train routes in 44 states. The inspection program began two years ago following a string of oil train accidents across North America, including a 2013 derailment in Quebec that killed 47 people in the community of Lac-Megantic. 16 ENERGY PIPELINE MAY 2017
Federal regulators said the inspections resulted in 1,118 violation recommendations and prompted railroads to be more responsive to inspectors and to improve safety. Union Pacific agreed to increase its inspection frequencies following the Mosier derailment under an agreement with federal regulators who said the railroad’s inspection program was too lax. Railroad spokeswoman Calli Hite said the railroad shares the railroad administration’s dedication to safety. “Union Pacific has always paid close attention to track conditions and inspections,” Hite said. Most violations were found in the months after the inspection program began in January 2015 in the Southwest, where officials said Union Pacific runs a majority of the oil trains. In many cases, violation recommendations came after the railroad did not respond quickly enough to problems found by inspectors, said Marc Willis, a spokesman for the railroad administration. Subsequent inspections turned up thousands of additional safety problems but far fewer recommendations for violations. That was because the high number of violation recommendations for Union Pacific sent a message to the entire industry to quickly address any issue raised by inspectors, officials said. “Railroads are paying closer attention,” Willis said, adding that derailments have fallen 10 percent since the inspection program began. “Although many minor defects still are being identified ... both FRA and railroad inspectors are finding fewer serious conditions, resulting in significant safety improvements.” The amount of oil moving by rail peaked in 2014 then dropped after crude prices collapsed. Major railroads reported moving more than 43,000 carloads of crude in the fourth quarter of 2016, down almost 50 percent from a year earlier, according to the railroad association. — By MATTHEW BROWN, Associated Press
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MORNING GLORY Triple Creek in the morning is a site to behold amid the sunrise on Greeley, Colo. The Triple Creek drilling pad came into Greeley amid a bit of neighborhood unrest, but with its electric drilling rig, the loudest noise seems to be the occasional clanking of pipes. At full build-out, Triple Creek will be a pad of 22 wells, producing oil and gas through Extraction Oil and Gas, based out of Denver. Photo by Sharon Dunn
Got a great shot in your oil patch? Send it and information about the picture to Energy Pipeline magazine Managing Editor Sharon Dunn sdunn@energypipeline.com.
METHANE MITIGATION FUELS U.S JOB CREATION, MINIMIZES WASTE FOR OIL AND GAS INDUSTRY New research offers an inside look at the methane leak detection and repair industry, showing that it saves money and time, and improve the environment, while also keeping people employed. The study, Find and Fix: Job Creation in the Emerging Leak Detection and Repair Industry, profiles the industry and its employees and assesses future growth potential, according to a news release. Specifically, the research, commissioned by the Environmental Defense Fund, found that the LDAR industry offers well-paying employment opportunities across the country that cannot be offshored, saves money by minimizing waste and keeping otherwise lost product in the pipe, and reduces emissions of a highly potent greenhouse gas along with other co-pollutants, thereby contributing to cleaner air for communities, the release stated. “The research ... proves that sensible regulations coupled with the right corporate commitments can help this burgeoning LDAR industry continue to create well-paying, boots-on-the-ground jobs in communities from coast to coast,” said Ben Ratner, director at Environmental Defense Fund, in the release. “Policymakers at all levels who are serious about creating American jobs should seize the opportunity to support the fast-growing meth-
ane mitigation industry, recognizing that economic development and environmental progress can go hand-in-hand.” The U.S. natural gas system — including the production, gathering, transmission and distribution of gas — is the nation’s largest industrial source of methane emissions, a potent greenhouse gas. Methane emissions also result in an estimated $1.3 billion in lost product each year for the oil and gas industry (ICF, 2014). The research is based on primary data collected from 60 leak detection and repair firms in the U.S. Datu Research’s study builds on 2014 research titled The Emerging U.S. Methane Mitigation Industry, which assessed the market landscape for companies providing solutions to reduce methane emissions from oil and gas operations. The follow-up study focuses on the subset of firms that perform leak detection and repair services specifically. — Staff Reports
MAY 2017 ENERGY PIPELINE 17
MAKING HOLE The first North Dakota oil well BY BRUCE WELLS • FOR ENERGY PIPELINE
After decades of dry holes drilled from one corner of the state to the other, in 1951 new technologies and true grit brought North Dakota’s first oil discovery. The well on Clarence Iverson’s farm endured blizzards and was “shot” twice before finally producing oil. The Amerada Petroleum well had been regarded with skepticism, but within two months of its completion, 30 million acres were under lease. The oil discovery in Mr. Iverson’s wheat field tapped a petroleum basin stretching from North and South Dakota, Montana, and into Canada. The amber-colored oil was of such high quality, “you could have run a diesel with it.” The Williston Basin was first described (and named) by W.T. Thom Jr., who reported “a great structural depression centering near Williston” in the summer of 1912 when he was a college sophomore studying geology as an apprentice for the U.S. Geological Survey. Thom had explored a creek bed near the Cannonball River, notes historian James Key. “It was his discovery of coral that led him to believe that the area was once inundated by an ancient sea.”
By the late 1930s, petroleum companies were struggling to overcome North Dakota’s difficult rock formations, including granite, which thwarted drilling technologies of the day. Despite repeated failures, the expensive lessons brought positive developments, according to historian Clarence Herz. “A more skilled labor force and continuous technological innovation that included the use of explosives, acid and newly invented scientific instruments meant an acceleration of the drilling process as wells were not only being drilled faster, but deeper and at a much higher cost,” he says. “Companies leap-frogged one another in anticipation of being the first to identify an oil producing zone.” Meanwhile, Thomas Leach, a former chief geologist for an independent oil company in Oklahoma, had been convinced for years oil could be found in North Dakota. In the late 1930s, he convinced Standard Oil of California to drill a well almost 2 miles deep there. The dry hole cost the company almost $1 million.
BRUCE WELLS, is the founder of American Oil and Gas Historical Society, a 501c3 nonprofit organization dedicated to preserving the history of oil and gas. He is a former energy reporter and editor who lives in Washington, D.C.
Amerada Petroleum, now Hess Petroleum, today operates a gas processing plant not far from the discovery well. 18 ENERGY PIPELINE MAY 2017
(Left) The first Bakken shale well was completed in 1953 on Henry Bakken’s farm - less than five miles from the Iverson No. 1 well. U.S. Bureau of Land Management map. (Below) “This Williston Basin discovery, Clarence Inverson No. 1, opened a new era for North Dakota,” notes a monument dedicated two and a half years after the 1951 oil strike. Photo courtesy BakenBlog.com.
After World War II, Leach and Tulsabased Amerada Petroleum decided to drill into the basin’s Nesson Anticline formation, about 50 miles northeast of Williston. The company chose a site on the Iverson family farm near Tioga and drilling began in September 1950. There was little to report until January 1951, “except the depth of the bit, the conditioning of the mud, and the occasional tripping pipe,” Herz says. Following a late January blizzard that shut down the well, drilling continued until
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total depth – 11,744 feet – was reached on Feb. 4, 1951. No oil was found. Amerada Petroleum decided to “shoot” the well. On March 1, multiple perforating charges were set off between “11,706 feet and 11,729 feet using Lane-Wells Koneshot,” Herz reports. Still no oil was found. “The Koneshot was a type of perforating gun that used a shaped charge. It was another innovation,” Herz says. “It contained shaped charges in a spiral placement in a
steel housing at a 3-inch centerline distance from each other.” Work was again halted by a severe blizzard in early March. The well remained idle for weeks until snow-choked roads could be cleared. With the well plugged back to a depth of 11,669 feet, work stopped to make repairs before the well was perforated again. At 12:55 a.m. on the April 4, 1951, the Iverson No. 1 well began producing about 240 barrels of oil a day. The state of North Dakota finally had its first oil well.
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Smart controller increases efficiency and lowers costs of small solar power systems BY GARY BEERS • FOR ENERGY PIPELINE
TECHNICAL INTEGRATION Is was not that long ago, we met our on-the-go communication needs by toting around a camera, portable phone, watch and laptop computer. Since each performed a separate function, we did not expect technical integration into a single communication device – but someone did and the smart phone arrived. Many industrial activities utilize component systems that do not appear to be candidates for integration, but clever engineers seize upon this opportunity and, boom, there is a break-through consolidated device that provides increased efficiency at lower cost.
TRADITIONAL CONTROLLER Many upstream operations in the oil and gas industry are in remote locales and rely on combinations of imported electricity, diesel engines, and solar power to supply energy to motors for moving liquids and gases. Recently, an integration of the electrical components of small scale, solar energy systems improved the efficiency of energy production with lower capital and operating costs.
FIGURE 1: TRADITIONAL CONTROLLER SYSTEM
20 ENERGY PIPELINE MAY 2017
The traditional components of a controller — which transform the energy output (wattage) of a solar panel into power usable by pumps, compressor, and other motors — are shown in Figure 1. These components are made by different manufacturers and, when assembled, occupy a cabinet about the size of a large refrigerator. Each array of components is a custom design based on the type of motor and associated input/output power requirements. Consequently, a change to a different motor will require a modification of the components. This specificity can be a discouraging factor to operators and their subsequent lack of interest in installing to solar power at a remote pad. They prefer off-the-shelf, simple units that require low maintenance.
SMART CONTROLLER A smart controller has been developed that integrates the five components into a single system (Figure 2). This universal unit can power any motor independent of phase, voltage, or frequency and works with or without a battery bank. Importantly, this smart device uses only one-half of the wattage capacity required by a traditional controller. For most small solar-energy systems,
For over 50 years, GARY BEERS, has worked in numerous fields of environmental science as a consultant, regulator and educator. This career included senior management position with major consulting, nonprofit and public organizations. He has founded several successful firms to capture emerging resource management markets. One of his latest ventures, EnviroScienceINFO, provides content for public media.
FIGURE 2: SMART CONTROLLER SYSTEM
this lower energy demand results in 50 percent reduction in total project costs and makes this option competitive with diesel power. An example of a smart controller, an circuit board which is housed in an yellow aluminum case about the size of a tissue box, is shown in Figure 3. The circuit board contains high-speed switching silicon, adaptive firmware, connections for wireless communication modules, and connections for external sensors. Adaptive firmware means software is embedded in the hardware and serves to operate the integrated components. This software can be accessed to update the programs, to meet the interface needs of added external devices, and to accommodate any unique needs of the customer. Incidentally, the smart controller contains no moving mechanical parts.
APPLICATIONS IN REMOTE AREAS While the smart controller only has been recently commercially available, there are many successful off-grid applications in the Third World, especially where solar power is the energy source for pumping irrigation water. This demonstrated performance in remote areas, with increased efficiency and lower costs, is peaking interest in possible application to isolated oil/ gas operations. In a remote area of Wyoming, a small solar panel unit with a smart controller is proposed to enhance the evaporation rate from ponds at a produced-water, disposal facility. With an increased evaporation rate, the functional size of the pond can be significantly increased and results in increased profits. The generated energy will power motors driving arrays of mini-spray units on the pond surface during the warmer months and arrays of subsurface bubblers during the colder months. The operations of these arrays are under the control of the smart controller with sensors that monitor wind speed and direction. As the wind dynamics change, the smart controller optimizes the performance of the arrays. Basically, arrays in the upwind areas of the pond are operated at higher levels than those in the downwind portion of the pond: this serves to limit over-spray. The efficiency and economy of the smart controller should attract possible use of small solar power systems to pump liquids and gases at oil/gas operations in remote locations. — For over 50 years, Gary Beers has worked in numerous fields of environmental science as a consultant, regulator and educator. This career included senior management positions with major consulting, nonprofit and public, organizations. He has founded several successful firms to capture emerging resource management markets. One of the his latest ventures, EnviroScienceINFO, provides content for public media.
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MAY 2017 ENERGY PIPELINE 21
DATA CENTER
The oil and gas industry is a large part of Colorado’s economy. Below, find statistics on drilling production, well permits and rig counts.
2017 DRILLING PERMITS
RIG COUNT BY STATE
COUNTY
NO. (% OF STATE TOTAL) 637 (70.5%)
Weld 124 (14%)
Garfield State
Colorado Louisiana Oklahoma New Mexico North Dakota Texas California Alaska Ohio Pennsylvania Wyoming
April 7 March Avg. Feb. Avg. Jan. Avg.
28 60 122 51 42 418 8 7 21 33 18
28 55 109 47 40 399 7 5 21 32 17
26 52 102 48 35 370 6 9 20 34 19
28 59 86 39 34 336 6 8 20 33 19
Source: Baker Hughes Rig Count, April 7
2016 GAS PRODUCTION
47 (5.2%)
Mesa Rio Blanco
29 (3.2%) 26 (2.9%)
Adams Jackson
2017 OIL
13 (1.4%)
State: 904 Source: Colorado Oil and Gas Conservation Commission as of April 1, 2017.
US RIG COUNT The U.S. rig count peaked at 4,530 in 1981 and previously bottomed at 488 in 1999. Area April 7 March Avg. Feb. Avg. Jan. Avg. U.S. 839 789 744 688 Canada 132 253 342 302 Source: Baker Hughes Rig Count, April 7
County *YTD‘16........................................Production Weld............................................... 52,271,816 (34%) Garfield.......................................... 47,016,521 (31%) La Plata......................................26,265,779 (17.2%) Las Animas.................................... 8,890,678 (5.8%) Rio Blanco...................................... 5,254,656 (3.4%) Mesa............................................... 4,227,998 (2.8%) State........................................................152,377,851
PRODUCTION COUNTY *YTD
Weld Rio Blanco Cheyenne Garfield Lincoln Larimer Adams Arapahoe State
‘17 PRODUCTION
8,128,246 (87%) 342,441 (3.7%) 176,335 (1.9%) 158,630 (1.7%) 104,941 (1.1%) 78,638 (0.83%) 67,812 (0.72%) 52,351 (0.56%) 9,296,134
Source: Colorado Oil and Gas Conservation Commission as of April 7
Source: Colorado Oil and Gas Conservation Commission as of April 7.
COLORADO ACTIVE WELL COUNT
22 ENERGY PIPELINE MAY 2017
Weld...........................................................................23,279 Garfield......................................................................11,231 Yuma............................................................................3,877 LaPlata........................................................................3,324 Las Animas..................................................................2,937
Rio Blanco....................................................................2,883 Adams.............................................................................956 Boulder ..........................................................................311 Larimer...........................................................................260 State..........................................................................54,332
Source: Colorado Oil and Gas Conservation Commission as of April 1
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