#Water well Drilling Company Calgary

[blackdogdrillinginc]

Water Well Drilling Alberta Need a well drilling contractor? Black Dog Drilling is a company that offers well-drilling services in Red Deer, Calgary, and Rocky Mountain, Alberta. Contact us at 403-396-6389.

[college-girl199328]

The most consequential date in 20th-century Canadian economic history was on Feb. 13, 1947, on a farm near Edmonton, when Imperial Oil made one of the oil discoveries in the world.

A plume of oil and flames reached 15 meters toward the sky Leduc No. 1 ushered in Alberta’s incredible oil industry. Within weeks, 500 oil companies were formed, launching Alberta and Canada into the Canadian economy and our standard of living.

Now, it appears as though history may repeat itself. Alberta’s Leduc geological formation contains lithium critical and rare metal vehicles and cell phones.

Lithium has traditionally been extracted from “hard rocks,” but in Alberta, it exists in the brine, or water, left behind in oilfields across the province. Geologist Chris Doornbos started E3 Lithium, a TSX-listed geo-tech company that entered a strategic partnership with Imperial Oil last year. And last week, the company announced some impressive test results.

“Our resource was upgraded (last week) to 16 million tonnes — 9.6 indicated and 4.6 measured reserves of lithium carbonate equivalent,” said Doornbos in an interview with the Financial Post. “This is five times higher than the estimated lithium reserves in the rest of Canada and potentially more than in all of North America.”

Like so many other discoveries, Doornbos came across lithium somewhat by accident. “I was looking for copper, but I examined the 2010 Alberta Geological Survey records, then we sampled water from aquifers in the old oilfields and found that lithium was plentiful in the brine water left behind oil production,” he said.

“As such, it is measurable and easily pumped to the surface for processing. It is not mining but will be conventional oil and gas production. We will drill wells, pump water to the surface, to an extraction plant, then put the water back down.”

Doornbos launched his company in 2016 and called it E3 “because lithium is the third element in the periodic table produced in the Leduc formation company.

Imperial holds freehold leases in the Leduc area, but E3 has collected drilling rights to a Leduc land position. “We have everything from Calgary to Edmonton, in the heartland of Alberta,” Doornbos said.

The company intends to build a commercial processing plant for E3 Lithium this commercial potential. Lithium is one of the critical metals and minerals listed by the United States for security purposes. I first E3 as a moderator for a panel discussion in Washington, D.C., about critical metals sponsored by the Canada-United States Law Institute.

“There is less risk because we know where it is and how big it is,” said Doornbos. “It’s not uncommon to find this amount of lithium in dissolved formation waters well-understood aquifers, producing oil since the 1940s have been 4,000 drill holes into Leduc, which means 4,000 geological data points. That’s unheard of. Most take five years to drill their first hole.”

He estimates that the Leduc geologic region encompasses 10 to 15 percent of the province. There are other lithium deposits in Canada, but most require traditional mining to produce.

“Alberta, if successful, will be its own lithium jurisdiction, paralleling the Lithium Triangle in South America and Australia’s hard-rock lithium mines,” said Doornbos. “Lithium is in demand for batteries because it conducts electricity easier than any other material. It is the lightest metal with the highest energy density.”

Alberta, one of the world’s great oil-producing regions, may end up the world’s transition to lithium batteries.

[market-daily]

Does Fracking Have a “Clean” Future?

“Oil shock” is officially no longer a historical term. While consumers panic at the pump, their governments confront an old truth: a lack of domestic energy supply is a national and global security issue. Soaring costs for developing, producing, transporting and refining crude oil are again pumping up inflation and interest rates worldwide, threatening a full economic recovery from the pandemic.

However, with enormous North American oil and gas reserves available, public perceptions around the environmental impact of oil and gas development are the primary barriers to lowering energy costs. Fortunately, the oil and gas sector has been innovating to dramatically improve the environmental performance of the sector’s processes, like hydraulic fracturing.

Abundant Reserves, Scarce Supply

Canada has the third-largest oil reserves in the world, and its oil industry meets far higher environmental, social and governance (ESG) standards than almost any competing jurisdiction around the world. Nevertheless, although it is an ideal source of ethical supply for its own needs and export, domestic political barriers have stifled resource development, especially pipeline infrastructure.

Unfortunately, for countries and consumers seeking cleaner oil options, this potential clean energy superpower imports oil from Saudi Arabia and other questionable suppliers, while most of its cleaner oil and gas industry has no direct access (aside from Newfoundland) to tidewater.

In the United States, energy dependence is also a result of domestic politics. US voters are increasingly concerned about carbon emissions, so the political establishment lacks the will to drill domestic oil resources. To avoid partisan roadblocks on the path to energy independence, the earth’s most significant and thirstiest economy needs to lower carbon emissions while increasing production.

However, as electric vehicles (EVs) have disrupted internal combustion engines, innovative energy service companies are now using technology to disrupt energy production with lower emissions.

Environmental Innovation

A great example of these innovators is RocketFrac Cleantech, a Canadian energy services start-up that uses rocket fuel as part of its process to stimulate reservoir production. Well-stimulating tight rock formations are usually done by hydraulic fracturing (more commonly known as ‘fracking’). However, RocketFrac Cleantech has developed proprietary innovations that allow the company to eliminate the use of freshwater, sand, and other additives in the well-stimulation process, getting the best of both worlds — stimulating production but with fewer carbon emissions and lower environmental impact overall.

The Calgary-based company’s approach can help move energy-rich countries like the United States and Canada closer to energy independence by improving the environmental performance of well-stimulation, addressing the concerns environmentalists have with conventional fracking’s carbon emissions, consumption of water, and risks of fracturing-induced earthquakes…..Read More

Source: Market Daily

[careerxlsstudyabroad]

Innovation Energy: The hot new fuel that could bring jobs and growth back to Canada’s oilpatch

~CXL~

Cheap, renewable geothermal power has the potential to meet the country's energy needs and put thousands of laid-off oil and gas workers back to work The energy industry gets a bad rap when it comes to innovation, yet the oilpatch is by far the largest spender on clean tech in Canada, to the tune of $1.4 billion a year. As part of its continuing coverage of the innovation economy, the Financial Post reports on the intersection of technology and energy, from the oilpatch in Alberta, off the shores of Nova Scotia to the plains of Saskatchewan.

In Calgary

A rig crew in late November 2018 arrived on a patch of prairie near Torquay, Sask., in the heart of the province’s most active oilfield to drill the deepest well in provincial history at 3,530 metres.

But the crew wasn’t trying to hit oil or gas. They were targeting a hot sedimentary aquifer for steamy, briny water to be used for Canada’s first geothermal power project.

“I think they truly enjoyed the challenge of drilling for something very, very different,” said Kirsten Marcia, chief executive of Saskatoon-based Deep Earth Energy Production Corp., which is developing the power project.

Marcia said the results of that well were so encouraging that the company will return later this year to drill a deeper well for the still-under-development, five-megawatt geothermal electric generating station that she hopes will be the first of many such plants in the country.

Read More at   https://business.financialpost.com/commodities/energy/innovation-energy-the-hot-new-fuel-that-could-bring-jobs-and-growth-back-to-canadas-oilpatch

[hockeyfun]

Auston Matthews #4

Requested by @verywell-fandango​ : One where x is a female hockey player and she goes on a date with auston to an ice rink and they play together if you can of course

Warnings: pain, cussing, and sexual tension

Word count: 3194

Author’s note: It’s a pretty long one Idk there is just something about Auston Matthews that brings out the most creative in me. I love writing stories about the main character playing hockey. Thank you so much for the awesome request.

You finally made your move to Toronto. You had just been traded from the the Calgary Inferno of the CWHL (Canadian Women Hockey League) to the Markham Thunder. It was a blessing and although all trades suck, you weren’t too mad about it. Your boyfriend was Auston Matthews, the star player of the Toronto Maple Leafs. You were finally going to be close to him again.

You had a very similar upbringing as Auston. You had grown up in Arizona, and you were 3 years old when you went to your first hockey game. It was an LA Kings game and you fell in love with the sport. When you were about 12 years old, it was obvious that you were excelling in this sport. Because the hockey culture in Phoenix on the the woman’s side was a bit underdeveloped, and to ensure that you kept growing in the sport, your parents made the transition to have you play in the boys league. That’s where you met Auston. You had played with him and his team for almost 4 years. At the beginning the two of you just clicked on the ice. It was obvious who the best on the team was. Like on most hockey teams, you became best friends with your line mates, but more specifically Auston. When Auston was drafted into the Juniors at 16, it was finally time for you two to separate paths in the hockey world. It was then that you made him promise that when he got to the NHL draft that he had to bring you.

You finished high school early at 17 and got recruited to go to school and play at an NCAA college, while also playing for the Woman USA national teams. Although Auston and you went separate ways, you still kept in touch and cheered for each other no matter where you were. While Auston was in Zurich you were finishing up at the University of Minnesota. You were young compared to everyone else, but it was all apart of the plan. You were a fast paced person and wanted to reach your goals as fast as possible hence why the graduating early. After your team won the National Championship, you were ready to move on. Taking summer school and playing your heart out for your school led you to be recognized in the women’s hockey world. Auston was proud of you, and when he realized that he was going to be picked in the first round of the NHL draft, he invited you, keeping his promise.

You accepted the moment he called you. You flew into Buffalo from Calgary on the day of. It was the first time you and Auston had seen each other in person since your younger days. You booked a hotel room in the same hotel as him and waited in the lobby after settling into your room. You were wearing jean shorts, a loose white tank top, and a light sweater over it. You weren’t wearing any makeup but mascara and your hair was naturally wavy. Auston remembers this moment vividly. You had definitely grown up. You filled out beautifully from your awkward athletic body as a 16 year old. He saw you first which let him take you in. Your glowing personally was radiating off of you as you talked to the random person next to you. He was with his mom when this happened, she saw it on his face right then. She knew her son had fallen in love. Finally you turned from the random person and saw Auston. You weren’t ready for the rush of emotions that caused you to physically launch yourself into his arms. “Auston,” you yelled. He caught you effortlessly and enjoyed having you close to him. You had pulled yourself apart from him but still held on. He had gotten bigger and stronger. He looked the same but completely different at the same time. You grasped his biceps taking him in. “Oh my gosh, Auston. You’ve gotten huge,” you commented. You looked up at his face, he let out a small laugh at your comment. Auston smelled good. It was a mixture of a warm vanilla and musk smell. It fit his latino background. After saying hello to his mom and later the rest of his family you departed from them to get ready for the draft. Auston was nervous for the night. Although he was certain he’d be going to the Toronto Maple Leafs, this moment was still nerve racking for him. It didn’t help that when he saw you in your dress with your hair and makeup done he was overtaken with even more emotions. You too were overtaken with pride when seeing Auston in his suit. There was another emotion lingering in the background that you only knew now as love. You could tell he was super nervous because he didn’t smile a lot at your quirky jokes. You wished you were able to sit next to him for this and help him calm down but you knew his family deserved it more and you were content just being there. You remember the emotions of hearing Auston’s name being called by the Maple Leafs. His entire entourage, including you, were crying. He hugged you last and in the quick second you told him how proud you were of him. Eventually after the first round you were able to go backstage to see him. You and his family saw him talking to some Maple Leafs personal. What you couldn’t hear was that they were telling him they wanted to do a bit of a tribute to his drafting, and they want to know who you were. The marketing woman fell in love with your friendship story. Two big stars in their hockey worlds having a path that crossed multiple times. As he was talking to them you wondered around. You wanted to see everything from this event, an event that every hockey player dreams of but one you’ll never experience because of being a woman. You met a few of the other draftees, like Pierre-Luc Dubois and Patrick Laine, eventually you returned to his family. Auston came over to you all and took in this incredible moment. His family wanted to celebrate by going out to eat. You politely declined to go with them. You knew they needed to celebrate without you. You decided to get something to eat at the hotel. You were in the lobby hanging out when Pierre-Luc Dubois, the third pick by the Columbus Blue Jackets, and his family came back from them celebrating. He saw you and remembered you so he felt comfortable coming to talk to you. He was obviously enraptured by you after getting to know who you were. He was in awe by your accomplishments as a woman’s hockey player. You didn’t realize how late you were talking to him till Auston and his family came back. They were obviously still on a natural high from the night as the came in a bit loudly. Your heart grew in happiness to see them like this. “Auston,” you yelled. He turned and his smile was evident until he saw you talking to PL. He motioned to his family to keep going. He came over to you and the vibe was obviously different for him. He saw the competition in PL’s eyes as the more he got protective over you. You noticed it but honestly you tried ignoring it but eventually it was too much. To diffuse the situation you told PL that you were getting tired and it was time for you and Auston to leave. You thanked him for a wonderful evening and congratulated him on his draft. He was taken aback a little but said his goodbye. Auston was silent most of the way up to your room. You finally asked him what was up when you reached your room. That’s when it all came out and he kissed you passionately for the first time.

Your relationship with Auston was history after that. It was hard as you both played professionally in other cities, but you guys did it. Now you were going to be living in Toronto with him. You two will be going back to Arizona for a few weeks since it was summer but you needed to feel a little more settled in Toronto before you left. You had only been there for a few days when Auston asked you if you wanted to train with him and the boys. You agreed. When you got into the Maple Leafs training room, you left Auston and company behind. They had a different regime for their workout. By the end of the two hours all of you were sweating your asses off, but you weren’t done. It was time to get on the ice. You had luckily brought your gear and went to a different locker room to change. It was your first time being back on the ice with Auston since playing with him as a kid. Both of your games had changed so much you were a bit nervous to have him see you play. After a few drills the workout got lazy. You all went to the bench to get some water, “Man, I’d really like to see you play,” Mitch spoke to you. “dude, she’s incredible,” Auston spoke proudly of you making your heart flutter. “We could play right now?” Morgan Rielly offered. Mitch grew excited by this idea, “Yes we should. We could play two on two.” You looked at Auston your boyfriend to see what he wanted to do. He shrugged at you as if to say ‘why not’. You nodded your head in agreement to his shrug. “I hate when you guys do that,” Mitch shook his head. You looked at him confused. “Do what?” “The communicating without talking thing,” he motioned between you two. You never really noticed that you and Auston did that but it was a bit funny now that he pointed it out. “Well get ready because me and my girl do it even better on the ice,” Auston joked back. He wrapped his arm over your shoulder. It reeked like most hockey gear does, “Ugh,” you shrugged it off, “you smell terrible.”

You skated to the middle of the ice with Auston. You were a bit nervous to play against all of them but even more nervous about playing with Auston. You hadn’t played with Auston since you were younger and although you had a more intimate relationship with the man, you were worried you wouldn’t click  with him like you used to. You breathed in and let your instincts take over. You didn’t have to think. Hockey was fast and your brain just did what you needed it do.Mitch and Mo weren’t ready for your ability. They were quick to recover. Playing with Auston was as easy as you remembered. The man was incredible and the two of you complimented each other well. The two of you found each other on the ice with ease. It seemed like you were always one step ahead of Mo and Mitch, but neither teams could score. You all were too evenly matched. Mitch had the puck and tried to fake a pass to Mo but instead slap shotted it towards the net. You were quick to get your body to block the shot. It hit you in calf of your leg causing a deep ripple of pain to break through your body. You didn’t scream but you let out a very intense cuss word. Your muscle began to spasm. The boys rushed over to you. Embarrassment coursed through your body because of their concern. Auston ripped of his helmet and gloves. “Are you okay?” he spoke frantically already untying your skate and getting ready to tear of your gear. “Stop,” you pushed his hands away, “I’m fine,” you lied. You weren’t sure if you were alright or not but the adrenaline helped you not feel the pulsing pain. “Just help me up,” you asked. “I’m so sorry,” Mitch spoke worryingly. You rolled your eyes at him trying to show him you were okay, “Mitch, I’m fine. I’m a hockey player this isn’t the first time i’ve been hit by a puck,” you reassured him. Auston glared at Mitch, to diffuse the situation you looked up at your boyfriend and held up your hand, “Matthews, I need help getting up and making sure I’m okay.” He turned to you full of concern. Mo ran off the ice to grab an ice pack. You stood up and felt the huge knot the puck had created in your calf but it was doable. The pain was bad but it wasn’t your worse. You played the national championship in Minnesota with a fractured ankle. Auston, Mitch, and the now returned Mo’s faces were filled with concern that made you angry. “I’m fine let's keep playing,” you commanded. “No, it’s too much. You need to see the trainer,” Auston spoke to you. You glared at him. Once again unspoken communication rippled through you both. He wanted you to see the trainer. You wanted to ignore it all. He understood your point though. You wanted to keep playing. You were angry and wanted to win the friendly completion game. You understood his argument too. He didn’t want you to get even more hurt. this game was irrelevant. You also fought that argument, you were having so much fun playing with Auston again. You didn’t want that to end either. Eventually you won the argument. “Okay, fine. next goal wins,” he rolled his eyes. “Yes,” you cheered. Mitch and Mo’s faces were still laced with concern. You could tell they didn’t want to keep playing. “I’m fine,” you spoke and skated around to show them you were. Your calf screamed in pain but you ignored it. They eventually accepted the only way to get you off the ice was for the competition to end. You were back to game mode. You played with a new intensity which caused the boys to also play with it. You had the puck and rushed it down the ice. You saw Auston in the corner matched up against Mitch. You tried to fake Mo out by a shot but it didn’t phase him. Eventually you saw an opening for Auston as he skated around the net. You passed it to him. He shot the puck but Mitch blocked it with his skate. It bounced off his skate near you. You pushed off the ice in pursuit to the puck. Mo wasn’t ready for your burst of speed and was a second too late as you shot the puck into the back of the net. You rose your hands in victory and heard Auston’s loud cheering come closer to you. He crashed into you while wrapping his arms around you and picking you up. He spun you around and once you were back on the ground he put his helmet close to yours. “That's my girl,” he whispered. You smiled at him. Pain still pulsing from your leg. “Okay, okay love birds. You wore me out,” Mo spoke. He was breathing loudly. Your adrenaline was finally settling down. “Help me off the ice,” you asked Auston. He nodded his head understandingly. He wrapped his arm around your waist and skated you both to the bench. “Next time, I want her on my team,” Mitch told you all. “No, I get her,” Mo fought back. Your heart swelled at the fact they wanted there to be a next time. “Sorry, guys she was my liney first,” Auston spoke over his shoulder. He never let you go as he practically carried you to the locker room you were using. He sat you down. It was just you two. Austin began unlacing your skates. And took them off for you. You two didn’t speak at all. You both worked in harmony to get both of your gears off each other. It was like you two were dancing. Finally you stood there in just shorts and a sports bra. Auston was also standing with just his shorts on. Your body close to touching his. Every hill and valley created by his muscles glistened with sweat. You were breathing heavy because of the dense tension in the room. Auston placed both of his large hands on your shoulders and gently pushed you to sit down on the locker room bench. He kept his hands on your shoulder. In this position he looked bigger and stronger than ever. “We still play well together,” you said through heavy breaths. “It’s not the only thing we do well together,” he suggestively replied. Your heart quickened at his words. He bent down. His lips just close enough for you to kiss but instead of stopping he kept going till he was kneeling on the ground in front of you. He took your hurt leg and placed the ankle on his shoulder. You took in a sharp breath. He turned to face where your leg was bruised. It was already an ugly deep color. It reflected the fact that it was definitely a bone bruise. Auston lightly touched near the bruise. You yelped in pain yet some of it was also in pleasure. Auston looked up at you. His big brown eyes sparkled under his eyelashes. He turned back toward your bruise and gave it a light kiss. Then slowly he continued kissing up your leg. You leaned your head back in bliss. This man was trying to kill you. He was taking his time upward. Chills ran through your body. His lips tickled and burned your inner thigh. He was just a few kisses away from where you wanted him to be when you heard a knock on the door and both your and Auston’s names being called. “Are you both in there?” Mitch asked. Auston was slow to move from his position but when he did you felt the lack of heat. “Yes, I’m just helping her get to her feet and get her to the trainer,” he responded a bit huskily. You didn’t hear a response from Mitch which made you assume he had left. Auston looked back down at you, “I really do need to get you to the trainer,” he sighed sadly. He began packing up your things. You tried to stand up to help him but you crippled from the pain in your leg. Auston was quick to drop everything and hold onto you. “I was not expecting it to hurt that much,” you whispered. “I’m fine,” you spoke and tried again. This time you were able to walk. You limped around. Each step you became more acquainted with the pain in your leg. Auston stared at you with so much concern and love. “You are one hell of a girl,” he spoke with pride, “now lets get you to the trainer and then home.” You nodded your head in agreement, “so we can finish what we started,” you responded.

[atlanticcanada]

N.L.'s troubled Terra Nova offshore oilfield saved by last-minute restructuring

The beleaguered Terra Nova oilfield off the coast of Newfoundland and Labrador could live to pump another day after its owners reached a restructuring agreement in the eleventh hour Wednesday.

The oilfield's seven owners will shuffle their shares and provide short-term funding for the project, rather than abandon the field entirely, a news release from Suncor Energy Inc. said.

The announcement comes a day after the company was expected to deliver a decision about whether the field would be shut down for good.

"Although this agreement in principle is not a guarantee, it sets a path forward in the next few months to secure a return to operations for many years to come," company president and chief executive officer Mark Little said in the release.

By Suncor's estimates, there are still 80 million barrels of oil left in the Terra Nova field.

Calgary-based Suncor Energy is the minority owner of the field and its stake in the project will increase to 48 per cent from about 38 per cent as part of the agreement, the release said.

Details about the other partners, including which companies might be selling their stakes and for how much, weren't immediately available.

The agreement must still be approved and finalized, and is contingent upon the Newfoundland and Labrador government coming through with its promise of more than $500 million in cash and royalty adjustments, the release said.

The Terra Nova oilfield is one of four offshore oil installations in the province and sits about 350 kilometres southeast of St. John's. It hasn't produced oil since December 2019.

The field operates using a series of wells drilled into the seabed and connected to a massive floating production and storage vessel through a network of cables and pipes.

All that infrastructure needs extensive maintenance and retrofitting work in order to keep the oil pumping, but Little has said that after the COVID-19 pandemic and a global crash in oil priced, not all of the project's partners were still on board to foot the bill.

By late 2020, when the work should have been completed, the vessel was bobbing in the water near St. John's, dormant and nearly deserted.

Dave Mercer, president of the union representing the oilfield's workers, said the news was an enormous relief.

"I'm elated that families can stay together and keep their mortgages and keep their homes," the Unifor Local 2121 president said in an interview Wednesday night, referring to the Terra Nova workers whose futures have been hanging in the balance.

In the months before production was halted in December 19, the Terra Nova field directly employed just over 1,000 people in the province, Suncor data shows. By March 2021, only 445 were left.

It's been an emotional and difficult time for the workers, whether they have managed to keep their jobs or not, Mercer said.

About 100 of them rallied Monday at the provincial legislature in support of the project. Though politicians belted out messages of strength and hope, some people in the crowd had tears in their eyes.

There was a heaviness, Mercer agreed, but now that can lift, he said.

"Don't get me wrong, there still a lot of paperwork ... and obviously it's agreement in principle," he said. "But it's the best knows that we could ever ask for at this time."

Suncor and the project's newly restructured partners will make a decision in the fall about proceeding with the work required to suck the remaining barrels of oil from the sea bed, Wednesday's statement said.

Premier Andrew Furey and Energy Minister Andrew Parsons issued a joint statement, saying they were happy with the news.

"We are optimistic that there will be even brighter days ahead for the employees and our province," they said.

Before restructuring, joining Suncor as co-owners were ExxonMobil with a 19 per cent stake, Equinor (15 per cent), Cenovus Energy Inc. (13 per cent), Murphy Oil Corp. (10.475 per cent), Mosbacher Energy Co. (3.85 per cent ) and Chevron Corp. (one per cent).

This report by The Canadian Press was first published June 16, 2021.

from CTV News - Atlantic https://ift.tt/2TznXDQ

[evstenroos]

Work We Love #2

From the archive: October 21st, 2020

SUPPORTING SMALL BUSINESS THROUGH & THROUGH

Born in Kyiv, Ukraine, Mariya Podeyko, owner and operator of AM CLEANING, travelled across 27 countries before settling in Ottawa, Canada — where she eventually met her soon-to-be-husband and future business partner, Andriy.

“I moved to Ottawa in 2013 from Ukraine to attend university, where I studied international development and environmental studies. Even though Andriy and I attended the same school, and only lived a few blocks away from each other, we didn’t meet until after graduation.”

After dating for a year, Mariya and Andriy decided to relocate to Calgary, Alberta, and shortly after, in September 2018, the couple launched AM CLEANING.

“The name conveys a few different meanings. We work early in the morning and finish by the afternoon, but it is also representative of my and Andriy’s first names — he is my A, and I am his M, and together, we are one another's home. A home is more than just a house or a structure. It’s about the way you feel when you are there. After travelling through and finding comfort, or lack of, in so many places around the world, I wanted to be able to help people feel that beautiful sense of nest."

Unlike large cleaning companies, AM CLEANING’s small but mighty team takes a holistic approach, tailored specifically to each client's unique needs and lifestyle.

Why did you decide to take a natural approach to cleaning?

I had so many different jobs as an immigrant — I’ve worked in many environments, like kitchens and banks, which exposed me to harsh commercial cleaners. These chemicals are poured down drains without any way to filter the water. Even though we can’t see it, they have a detrimental impact on the environment. When I was still living in Ottawa, I came across a picture of Lake Louise, and at first, I couldn’t believe it was real. It was so ungodly beautiful. I was completely captivated by the clear, teal-coloured glacial water. I wanted to see it in person and enjoy, as well as preserve, the purity that nature offers us. Shortly after, I made the switch to all-natural, low toxic living. It started with personal care and then cleaning products.

 When Andriy and I moved to Alberta, I was so excited to be able to visit Lake Louise. It was during that trip that I thought "if I decide to open a cleaning company — an industry with a notorious carbon footprint — it has to be dedicated to natural cleaning". Rather than using harsh cleaners like bleach, CLR, and Vim, AM CLEANING utilizes steamers, scrub brushes, and other tools like drills to get rid of grease and dirt.

Photo by Rose Range Photography

When did you meet Ellinor, and how did you know she was the right person to design your ring?

Being a small business owner, I know how hard it is to be a self-employed human. When Andriy started talking about proposals and the ring, I knew I didn’t want to go to Tiffany’s to pick out a diamond. We live in a world where everything is mass-produced, and I wanted my ring to be more than an object. I wanted it to be made by a human who I know, who lives in my city, who I could meet at my local grocery store. That was really important to me. We found Ellinor through Instagram — her work is beautiful, and she is also European, so we liked her modern European style.

Working with her was such a cool experience. It was so much more than just going to a store and having something boxed up. You get to pick out your stones, decide on the width of the band…it’s a custom approach, which is what I live for. The way Ellinor approached working with us was very similar to how my own business operates. No house is the same. Instead of asking a client for the square footage, I want to know what their lifestyle is like, how they feel in their house, and what areas are used most often. Ellinor asked us similar questions about our lives — how active we were, what are the things that drive us crazy — and then used these answers to create a practical design just how I create practical, personalized cleaning appointments.

Photo by Rose Range Photography

Instead of going the traditional route and choosing a diamond for your ring, you picked a Montana Sapphire — can you explain the significance behind that decision?

When we arrived in Calgary, we went on our first camping trip to Waterton National Park, which is right on the border of Alberta and Montana. It was awesome — we went on one of the most beautiful hikes around Crypt lake. You can also take boat tours over Waterton lake, and at some point during the trip you cross the border and go into Montana. It was during our time in Waterton where we connected with and reaffirmed our love of nature.

We decided we no longer wanted to live a lifestyle that could spoil or impact our environment. We want to be mindful of consumption and resources because everything was so untouched and so pure. Three years later, when Andriy was thinking about the stone for my ring, he knew he didn’t want a diamond but rather a stone with significance. We liked sapphires but hesitated because they are primarily sourced from Sri Lanka, and we have no connection there. Then Ellinor told us sapphires come from other parts of the world like Montana — which symbolized so much for us: the lake we crossed was the colour of a sapphire, exploring nature in Alberta, the first hike we took in our new home. And in a way, this sapphire was locally sourced since it came from North America.

How did Andriy propose to you?

He proposed to me on August 15th while highjacking my maternity photoshoot in Horseshoe Canyon, Drumheller — our first child is due any day now — which was very convenient for him. Then he took me back to Waterton National Park, and we stayed at the Prince of Wales Hotel for three days. Stay Connected: @amcleaning_yyc www.amcleaning.ca

Learn more about AM Cleaning’s all natural cleaning products here

OUR MONTHLY FAVOURITES: CHECK OUT WHAT ELSE WE'VE BEEN LOVING

Nearly 30 years ago, Candace Larsen, a now master framer, began her career in the art and framing business.

"What I find so rewarding about working in this field, is the comprehensive nature of the process. The consideration of design requirements coupled with the practical nature of my materials, and how together it results in a finished piece. The presentation of which is the happy capstone of my craft. Besides handling the more traditional artist materials, Larsen's time working in galleries and completing her BFA in Jewellery/Metalworking gave her the skills she needed to work with less common materials, like stone, ceramics, and mixed media objects.

"We recently had some artwork framed by Candace out of the CK gallery, for our new place and it was an absolutely fantastic interaction," says Ellinor Stenroos.

The Eden is a family owned & operated bistro, located on 9 Avenue in the heart of Inglewood, serving classic comfort dishes in a casual atmosphere.

"The EDEN quickly became one of my regular spots three years ago for great, feel-good food, and a warm and welcoming atmosphere. It's suitable for business meetings, jewellery design consultations, and a happy hour cocktail after a busy week. Even during the pandemic, the EDEN has been a regular comfort treat for us!" — Ellinor Stenroos.

The Eden is celebrating its 3 year anniversary with a new menu, launching this week and you can be sure Ellinor will be there to check it out.

W1A is a British comedy series on Netflix that revolves around the awkward and humorous personalities at the BBC office, following the arrival of Ian Fletcher (Hugh Bonneville), the new Head of Values.

"David and I thoroughly loved and laughed our way through W1A. The satire is spot on and relatable to anyone who’s ever been tangled up in bureaucracy of a work-place," raves Ellinor. "Having lived, studied and worked in the UK, I find the humour not just charmingly dry in a British way, but the office characters' stereotypes are beautifully portrayed while still being wonderfully entertaining. Absolutely brilliant!"

[carsaloncalgary-blog]

Benefits of Paint Protection Film Installation In Calgary

A lot of car manufacturers in recent times have switched to water-based paints. These are good for the environment and shave off a few dollars for the car manufacturers as well. However, what it gives the end customer is a softer, feebler paint that chips easily and fades very quickly. Now we’re all for being environmentally friendly but we pay dearly for our cars to look and feel nice. We would always recommend a Suntek paint protection film installation on your car. There are several benefits of a paint protection film and we’ll look at a few of them in detail.

Benefits Of Paint Protection Film Calgary

1) Paint Protection

This one is a bit obvious but the number one reason to install a PPF in Calgary is to protect the paint on your car from chips and fading. Forget about going off-road on a trail like the Deerfoot trail (which is known as the rock chip capital of Canada), but even on regular roads the chances of having debris accidentally chip away the color from your car is extremely high. Protect your exteriors by installing a PPF from a respectable mechanic shop in Calgary.

2) No Additional Maintenance Required

We use the Suntek paint protection film, it has a lot of advantages over other PPFs and is superior in quality. What we like about the paint protection film is that it does not require any additional maintenance. You simply install it and let it do its job while you drive around carefree. Simply wash and clean your exterior as you normally would.

3) No Drilling Or Chemical Adhesives Required

Another benefit of using a paint protection film on your car is that you don’t need to use additional adhesives on your car to have the film stick to the exterior. The film already has an adhesive that is safe for your car paint and installs extremely easily. You don’t need fasteners, drilling or any other additional effort to install the film

4) Lifetime Warranty Available

We are so sure about the work we do and the materials we use that we provide a lifetime warranty against peeling of the film, against bubbles appearing on your car where the film has not been installed properly, and the film turning yellow due to exposure to the environment. We take our handiwork very seriously and we only use the best paint protection film available in the market – Suntek Paint Protection Film. If you don’t believe us we’ll be happy to give you references of any of our happy customers who’ve had the paint protection film installed at the best auto workshop in Calgary – The Car Salon

5) Extremely Clear and Undetectable

Most car owners are hesitant to use paint protection films because when not installed properly you can clearly tell there is some sort of plastic coating on your car. This not only looks bad, but it can be pretty harmful to the actual paint of your car. When installing a paint protection film in Calgary, always make sure to visit a professional auto shop certified in the installation of PPF. If you’re looking for the best in the business get in touch with The Car Salon to install PPF today!

Conclusion A paint protection film is absolutely crucial, especially in Calgary. There are plenty of auto body shops in Calgary that claim to be able to give you the precise finish that will have your car looking spanking new all over again but only one company, The Car Salon, can back those claims up with verified customer testimonials. If you are looking to protect your car paint with a film, get in touch with the best in the business.

[hopemcilroy]

Infographic Research - Chilean Mine Disaster

Where was the mine located?

The San José copper–gold mine was located in the Atacama Desert 45 kilometers (28 mi) north of the regional capital of Copiapó, in northern Chile.

What are some facts about the mine?

Coal mines are typically a lot shallower than gold and copper mines. In the United States, gold and copper mines can go as deep as 8,000 to 9,000 feet (2,400 to 2,700 meters), while the deepest coal mines are only around 2,000 to 2,200 feet (609 to 670 meters) deep, Kravitz said.

Coal mines also usually run horizontal to the earth's surface, while gold and copper mines can run any way.

Copper and gold mines don't leak methane gas and thus don’t present this risk. Copper and gold mines also can have large pockets of oxygen, which allowed the trapper miners in Chile to survive.

Copper and gold mines also are typically "wet mines" which drip water from the walls that can serve as a drinking supply.

Who owned the mine?

The mine is owned by Empresa Minera San Esteban, a company notorious for having a poor safety record and suffered a series of accidents. In 2007, an explosion in the San Jose mine is reported to have killed several workers.

What caused the disaster?

The cause of this mine was a cave - in. The mine that collapse had a history of instability that had caused previous accidents, including death. Chile has a long tradition of mining, during the 20th century they made it as the world top producer of copper. According to a review of data collected by the state regulatory agency (Sernageomin data), since the year 2000, it is found out that there is an average of 34 deaths every year due to mining activity in Chile, with a peak of 48 in the year 2008. (Ethiraj, 2010) 

How many men were involved?

33 men in total where trapped. When the collapse occurred there were two groups of miners. A dust cloud rose during the collapse, causing enduring eye irritation; blinding the miners for six hours. A first group of miners were near the entrance of the mine and escaped straight away without incident. The main group of thirty three miners was deep inside the mine—that consist of local workers and some subcontracted employees from a different company; who was unfortunate because they would not normally have been with them (Ethiraj, 2010). 

How long were they trapped?

They were believed dead for 17 days before they made contact to rescuers, but were trapped in the mine for 69 days overall.

What food did they survive on?

Every 48 hours they had 2 spoonfuls of tuna, half a cookie and half a glass of milk each. After 17 days food, water and medicine (hydration gel, soup)was lowered to them. The men quickly established a regular meal schedule - breakfast, lunch, afternoon tea and dinner. Doctors then transitioned them to a meat and rice diet, strict 2200 calorie diet - this kept them slim enough to fit in the evacuation chamber. The was a 3.19-inch-wide supply line made which provided them with food, water, and nutritional supplements such as vitamin D, which can replace the nutrients they are not getting from sunlight.

What did they do while they were there?

They split into 3 teams taking 8 hour shifts at either - working(they helped the rescue efforts), sleeping(they used lights/lamps to simulate light) and playing/entertainment(they played cards, dominos, live feeds of Chile football games, small music players, Bibles and smokers had nicotine gum). They had a small high-definition camera which allowed them to record their situation - where despite the disaster they made jokes on film. Working in shifts 24 hours a day, the miners had to keep the passage clear with the industrial-sized battery-powered sweepers, shovels and wheel barrows trapped in the mine with them. The miners had to remove on their own a total mass of drilling cuttings estimated at up to 700 metric tons.

When did they first make contact to families?

They were able to make contact via letters to their family and a 20 second voice conversation 20 days after they were initially trapped. Although, 10 days later they were able to have a video call with their families when a cable was lowered. 

What were the health risks?

Decades of research has shown the human body is built to function on the rhythm of the rising and setting sun. If sunlight doesn’t tell our brains when we should be asleep—and if we don’t eat, exercise, and sleep on a fairly regular daily schedule—humans can develop all sorts of health problems over time, from irregular metabolism to heart disease to deficiencies of key vitamins. To feel the effects of those disruptions each day would be like trying to live life in a constant state of jet lag.  A tired miner could sink slowly into depression, leading to debilitating emotional issues before or after he returns to the surface. He could make a mistake as the group works to build the bottom part of its rescue shaft, injuring himself or another miner at a time when none of them has access to emergency medical care. A miner already at risk for diabetes could develop it if he lacks a daily eating and exercise routine. All these risks only grow with time.

How did they survive the darkness?

One way to keep the miners on a daily routine is to simulate light and dark periods during each day. The men have already designated light and dark areas in the roughly half-mile-long tunnel where they are living, but the battery-powered lamps in the lighted areas may not be bright enough to trick the men’s internal clocks into thinking it’s daytime. “If you have really dim light, you can still read a newspaper, but that’s not enough to synchronize a 24-hour clock,” says Charles A. Czeisler, who directs the sleep medicine division at Harvard Medical School. Chilean authorities, were aware of these risks, and made the miners’ daily routine a priority. Each miner had daily jobs to do as said above.

What was the environment like?

The mine was 2km long and 625m deep(2 eiffel towers) where temperatures rose to 35oC with 95% humidity. 

How were they rescued?

An escape shaft was completed over 41 days and finished on October 9th which lead to the emergency rescue chamber for them to be rescued. There were 3 plans to drill down to the miners. A huge rock the size of 2 Empire State buildings was rescued.

Plan A -  Plan A used an Australian built Strata 950 model raise borer type drilling rig often used to create circular shafts between two levels of a mine without the use of explosives. The drill was provided by South African mining company Murray & Roberts, who had a recently idled machine in Chile for a separate mining contract. The drill had just finished a shaft for Codelco's Andina copper mine in Chile and was immediately transferred to San José. Since it weighed 31 short tons (28 t), it needed to be shipped in pieces. The Strata 950 was the first of the three drills to begin boring an escape shaft.

Plan B - Plan B involved a Schramm Inc. T130XD air core drill owned by Geotec S.A. (a Chilean-American joint venture drilling company) that was chosen by Drillers Supply SA (the general contractor of Plan B) to widen one of the three 5.5 inches (14 cm) boreholes that were already keeping the miners supplied with palomas.The Schramm T-130 was directed to bore toward the workshop, a space that was accessible by the miners. The T-130 became operational on 5 September and worked in three stages. First, it needed to enlarge the 5.5 inches (14 cm) hole to a 12 inches (30 cm) hole. It then needed to drill the 12 inches (30 cm) hole into a 28 inches (71 cm) diameter hole. “If we tried to drill from a 5.5 inches (14 cm) hole to a 28 inches (71 cm) hole, the torque would be too high and it would ... put the drill bits under too much pressure,” said Schramm, Inc. Latin American Regional Manager, Claudio Soto. However, by reusing the same hole, there was still added pressure on the drill. Delays occurred because of issues with the neck of the drills caused by the angle of the drilling. Rescuers couldn’t drill vertically since that would require placing the heavy rig on the unstable ground where the cave in had happened. And the rescuers also had to avoid drilling into the production tunnels that wind above the shelter. Soto added, during the rescue, “It’s a difficult hole. It’s curved and deep. The hard rock has proven to be abrasive and has worn out the steel of the drill.”

Plan C - Plan C was a powerful Canadian built RIG-421 oil drilling rig operated by Calgary-based Precision Drilling Corporation and was the last drill to become involved in the rescue process; it began drilling on September 19.The rig is a special drill used for oil and gas drilling that could drill a wide enough escape shaft in a single pass without a pilot hole. RIG-421 is a Diesel-Electric Triple that was 43 meters (141 ft) tall and needed 40 truckloads to bring its pieces from Iquique, Chile to Copiapó. It suffered a setback due to the difficulty of aiming the larger drill at a 2.5m x 2.5m target and the hardness of the rock when the drill diverted from its course. The drill then needed to be removed, resized and repositioned, which slowed its progress.

“We’ve drilled wells all around the world. The actual drilling of the hole in the ground isn’t that difficult. When you’re given a target to aim for it’s a little more difficult,” said Shaun Robstad, superintendent with Precision Drilling. 

RESULTS OF DRILLING

The widened shaft of Plan B's Schramm T130XD reached the trapped miners at 08:05 CLDT on 9 October after a 10-hour stoppage to change the drill-bit. By 8 October, the Plan A Strata 950's pilot hole had reached 598 meters (1,962 ft) deep (85% - it had not yet started its widened shaft). Plan C's RIG-421, the only machine at the site which drills a shaft wide enough immediately, reached 372 meters (1,220 ft) (62%).

What was the role of the Phoenix?

The Chilean engineers alongside the US Space programme built this escape capsule - safety device. The capsule, dubbed "Phoenix" after the mythical bird that rose from the ashes, carried the men nearly half a mile through solid rock in a shaft just wider than a man's shoulders as their two-month ordeal came to an end.The miners were kitted out with special lightweight, made-to-measure waterproof clothing for the rescue. They also wore a heart rate monitor which measured their vital signs as they were lifted to the surface. They wore a small oxygen mask and headphones and a microphone allowed them to be in constant contact with the surface. Elastic bandages around the lower legs were used to prevent blood circulation problems on the ascent.Doctors had been worried about the miners' eyes after the months they have spent without any sunlight. Each man was given dark glasses to avoid damaging their eyesight.If the capsule had got stuck, the men could have released a series of levers inside the capsule allowing it to be winched back to the bottom of the mine.But in the end, the journeys up and down the shaft were without incident. Journey times also sped up as the rescue progressed - from about 20 minutes per ascent at the start, to about eight minutes towards the end.

Rough timeline of events.

August 5th - The miners were believed to be dead.

August 22nd - Rescuers found them and there was a note sent up from the miners to let all know they were all alive.

August 23rd - Food, water and medicine was sent to the miners 

August 25th - 1st contact with family

August 29th - The miners moved to a dry room a little deeper and more spacious than where the initial cave-in was.

September 4th - The miners were bale to make contact with their families as cabling was lowered allowing them to have video calls.

September 17th - After the drilling had started, Plan A reached the miners but the problem was it needed widened.

September 18th - Plan B drill now reached the miners but it also needed widened.

September 19th - Plan C drilling starts after both Plan A and Plan B look that they are going to fail.

September 30th - The families of the miners claim $12million dollars in damages.

October 13th - First miner is safely rescued.

October 14th - All 33 miners alive and rescued.

The aspect of faith helping them through.

"You have to have faith," Galleguillos said. "You can never lose your faith. Faith is nourishment ... Faith is life."

Faith, even without hope. Shift foreman Luis Urzua was the first person to be heard once verbal contact was made with the miners. His first words were, "We are well and hoping that you will rescue us." Urzua said he doesn't believe in luck, but he does believe in faith -- even when it seems like there is no hope."The devil couldn't do anything because God was present," he said. Urzua recounted a time in the mine when one of his colleagues became ill. The prayers of the other miners, Urzua said, healed him. "We made a prayer, we prayed in front of him," he said. "The next day, he was better. ... He was doing better than all of us."That power of prayer stayed with the miners throughout their time underground."When we prayed, we didn't pray to get rescued; we prayed for the people outside not to abandon us," he said.It was another answered prayer.

What was life like after the rescue?

The miners had to wear special glasses to protect their eyes from the sunlight they hadn’t experienced in nearly 70 days. The miners had to go under a medical investigation, sent to a field hospital need the mine and once the condition of the miners was stabilised they were transferred to a medical centre in the Copiapó region.

[mikemortgage]

The highest gas bills in Canada about to get higher as East Coast production dries up

Consumers and businesses in the Maritimes already have the highest natural gas bills in the country and that’s not likely to get better anytime soon due to an increasingly unsettled East Coast energy sector.

At the centre of the current unease is the shuttering of Nova Scotia’s offshore natural gas production after the plug was pulled on the Sable Offshore Energy Project, some 200 kilometres into the Atlantic Ocean, in December.

Sable, which began production in 1999, provided a domestic source of natural gas and delivered $1.9 billion in royalties to the Nova Scotia government during its lifespan.

The plant’s closure, by operator ExxonMobil Canada Ltd., was preceded by the loss of Encana Corp.’s Deep Panuke Offshore Gas Project, which was capped in May 2018. Production at Deep Panuke started in 2013, but never met expectations and didn’t become the Sable replacement it was supposed to be.

Gas rigs are towed out of Halifax Harbour in 1998 bound for Sable Island.

The result likely means higher prices for natural gas in the Maritimes in the short term and possibly much longer if calls for renewed onshore gas development, a contentious but potentially lucrative issue for cash-strapped provincial governments, aren’t heeded.

“We do believe the closures of Deep Panuke and Sable will result in higher gas prices in the Maritimes,” said Steve Moran, chief executive of Corridor Resources Inc., a junior oil and gas company based in Halifax, which stands to benefit now that the biggest local sources of gas are gone.

'Crisis of our own making': Regulatory logjam has cost $100B in cancelled resource projects

Fed up with low prices, rivals that produce 20% of Canada’s natural gas team up to build own LNG project

Hate mail and vitriol: Divisions run deep over bill that could reshape our natural resources economy

Corridor produces natural gas in the McCully Field near Sussex in southern New Brunswick, though only during the winter when prices are strong. It is now eyeing further development in the province’s Frederick Brook Shale, a hydrocarbon-rich layer up to 1,100 metres thick.

“That’s the prize. Our main focus in 2019 will be trying to secure a joint-venture partner for the Frederick Brook Shale,” Moran said. “Certainly, high natural gas prices enhance the potential for future expansion in New Brunswick.”

Corridor’s expansion ambitions are also being aided by the New Brunswick Progressive Conservative government’s warm approach to hydraulic fracturing, which fractures layers of shale to release pockets of gas by pumping water and chemicals under pressure deep underground.

Premier Blaine Higgs, a former Irving Oil Ltd. executive, has moved to renew natural gas development in the province, although the government said a province-wide fracking moratorium remains in place.

“The provincial government has given all indications that they’re interested in new investment in the oil and gas sector in New Brunswick and are actively speaking with potential investors and potential proponents and developers,” said Colleen Mitchell, president of the Atlantica Centre for Energy, an industry group.

Corridor has not determined when it might frack again in New Brunswick. But Mitchell predicts new gas development will arrive in New Brunswick in 2020.

A domestic supply from onshore sources would help shield consumers from rising prices, she said, in part by avoiding pipeline tolls that must be paid to import gas through the 1,101-kilometre Maritimes and Northeast Pipeline, which connects Nova Scotia and Massachusetts.

“There is a significant threat to natural gas users with the traditional supply of natural gas ending,” Mitchell said, referring to Nova Scotia’s offshore supply.

Nova Scotia and New Brunswick natural gas customers already pay the highest average residential gas bills in Canada, according to the National Energy Board.

Bills in those provinces average nearly $160 a month, roughly double the averages in British Columbia, Alberta and Saskatchewan, where consumers can access large amounts of low-cost gas through well-developed pipeline systems. Nova Scotia and New Brunswick are not as well connected to North American gas markets.

“Our prices here are higher,” said John Hawkins, president of Heritage Gas Ltd., the only natural gas utility in Nova Scotia.

Heritage, owned by Calgary-based AltaGas Canada Inc., supplies residential, commercial and industrial customers, and the vast majority of its supply used to arrive from offshore sources.

Hawkins said prices for Heritage customers will increase in the near term, but will eventually stabilize thanks to two long-term transportation contracts that will bring in gas from hubs in Ontario and the U.S.

Heritage is also planning to store gas — bought at lower prices during the spring and summer — in a large storage facility, which Hawkins expects to be online by 2022.

Storing relatively cheap gas for winter use will cut Heritage customers’ gas costs by 15 to 20 per cent, he said. To further lower costs, he’d like to see domestic onshore gas development.

“We think it would be very helpful to have that happen here in Nova Scotia and New Brunswick,” Hawkins said.

Patrick Brannon, director of major projects at the Atlantic Provinces Economic Council, said onshore natural gas development holds “tremendous” though currently unlocked potential.

“We have billions of dollars potentially of onshore natural gas reserves, but nothing can move ahead until there’s some movement (on the moratoriums),” he said, referring to fracking bans in Nova Scotia and New Brunswick. “It’s definitely an opportunity for Nova Scotia and New Brunswick. Doing nothing isn’t really an option.”

Offshore development is also quiet, with no exploration underway in Nova Scotia, although the provincial government said the future of offshore exploration “remains positive.”

In a statement, the Department of Energy and Mines said it regularly has discussions with “major global” companies.

“There’s a tremendous amount of oil and gas out there — eight billion barrels of oil and 120 trillion cubic feet of gas,” the department said. “This is a long-term process, and we need to be patient. When the time and market conditions are right, there will be more activity.”

  Horses in Sable Island National Park Reserve.

The Canada-Nova Scotia Offshore Petroleum Board, a provincial regulator, issued a new call for exploration bids in December for an area around Sable Island, a national park.

In response, more than 3,300 letters of concern have been written to federal and provincial politicians that call for the bidding round to be cancelled, according to the Halifax-based Ecology Action Centre.

“Seismic blasting for exploration, and the chance of a blow-out or spill near Sable Island National Park Reserve pose undue risks to the entire ecosystem,” said Stephen Thomas, the centre’s energy campaign coordinator.

The centre is among a number of parties calling for a moratorium on both offshore oil and gas drilling in Nova Scotia and a public inquiry into the Canada-Nova Scotia Offshore Petroleum Board.

There are also environmental concerns about the proposed construction of a liquefied natural gas (LNG) terminal in Goldboro, N.S., which could offset the loss of offshore production jobs in the province.

Thomas said the terminal would be Nova Scotia’s single-largest source of greenhouse-gas emissions.

“It’s so energy intensive to liquefy natural gas,” he said. “I don’t see how we could ever move forward with building that plant and meet any climate targets in the future.”

But Brannon, at the Atlantic Provinces Economic Council, notes the $10-billion project would bring 3,500 construction jobs over four years, though the project’s proponent — Calgary-based Pieridae Energy Ltd. — has not made a final investment decision. If constructed, the terminal would be used to export North American LNG to Europe by sea.

    from Financial Post https://ift.tt/2SzDYmY via IFTTT Blogger Mortgage Tumblr Mortgage Evernote Mortgage Wordpress Mortgage href="https://www.diigo.com/user/gelsi11">Diigo Mortgage

[jamesgeiiger]

B.C. regulator says fracking caused earthquakes near Fort St. John

FORT ST. JOHN, B.C. — The B.C. Oil and Gas Commission has blamed fracking for three earthquakes in northeastern B.C. last month.

The provincial regulator says the events 20 kilometres south of Fort St. John on Nov. 29 occurred because of fluid injections during hydraulic fracturing at a Canadian Natural Resources Ltd. wellsite.

The events, which were felt but caused no surface damage, measured 3.4, 4.0 and 4.5 magnitude.

Fracking operations within the lower Montney formation were suspended after the earthquakes and are to remain suspended at the multi-well pad involved pending the results of a detailed technical review.

The commission says seven wells into the upper Montney formation had previously been drilled and completed by the Calgary-based company at the well pad with no seismic events larger than magnitude 2.5 detected.

The immediate shut down of operations is required when an induced seismic event in that region reaches or exceeds a 3.0 magnitude.

Hydraulic fracturing involves injecting water, sand and chemicals into a well under pressure to break up tight underground rock and free trapped oil and gas.

Companies in this article: (TSX:CNQ)

B.C. regulator says fracking caused earthquakes near Fort St. John published first on https://worldwideinvestforum.tumblr.com/

[startupcanada]

Parex Announces 2018 Second Quarter Results

CALGARY, Alberta, Aug. 08, 2018 (GLOBE NEWSWIRE) — Parex Resources Inc. (“Parex” or the “Company”) (TSX:PXT), a company focused on Colombian oil exploration and production, announces its unaudited financial and operating results for the three months ended June 30, 2018 (“Second Quarter” or “Q2”). All amounts herein are in United States dollars (“USD”) unless otherwise stated.

A conference call to discuss the Second Quarter results will be held on Thursday August 9, 2018 beginning at 9:30 am Mountain Time.

2018 Second Quarter Financial and Operational Highlights

Quarterly production was 42,625 barrels of oil equivalent per day (“boe/d”) (99% crude oil), representing an increase of 5 percent over the previous quarter ended March 31, 2018 and an increase of 24 percent over the three months ended June 30, 2017;

Earned net income of $188.6 million ($1.21 per share basic) compared to a net income of $3.5 million ($0.02 per share basic) in the three months ended June 30, 2017;

A voluntary tax restructuring with a cost of $137.5 million was completed in the quarter generating additional income of $239.2 million for a net income benefit in the quarter of $101.7 million. For the first six months of 2018, Parex has earned $260.1 million of net income;

Generated adjusted funds flow from operations of $121.7 million ($0.78 (or CAD $1.01)1 per share basic) which has been adjusted to exclude the $137.5 million ($0.88 per share basic) previously released cost of a voluntary tax restructuring completed in June 2018 which will be funded from existing working capital;

Including the $137.5 million voluntary tax restructuring cost, funds flow from operations was $(15.8) million ($0.10 loss per share basic) as compared to $0.34 per share for the three months ended June 30, 2017 and $0.65 per share for the three months ended March 31, 2018;

Capital expenditures were $100.6 million in the period compared to $59.0 million in the three months ended June 30, 2017. 2018 year to date capital expenditures are $158.8 million;

Working capital was $66.1 million ($323.1 million cash and cash equivalents) at June 30, 2018 compared to $205.8 million at March 31, 2018 and $128.3 million at June 30, 2017. The Company has an undrawn bank credit facility of $100.0 million; and

Participated in drilling 18 wells2 in Colombia resulting in 10 oil wells, 1 disposal well and 7 untested wells.

(1) Using USD-CAD Bank of Canada 3-month average exchange rate of 1.291 (2) Oil wells: Bacano-7, Coyote-2, Coyote-3, Jacana-22, Tigana Norte-8, Tigana Suroeste-4, Tigana Suroeste-6, Tigana Suroeste-8, Tigui-1 & Tigui Sur-1; Disposal well: Capachos Sur-2; and Untested wells: Totoro-2, Totoro-3, Totoro-4, AB-13, AB-16, AB-17 & AB-BA.

    Three Months Ended Six months ended     June 30, March 31,  June 30,   2018 2017 2018 2018 Operational         Average daily production         Oil & Gas (boe/d)(1) 42,625 34,291 40,586 41,612           Average daily sales of produced oil & natural gas         Oil (bbl/d) 41,734 33,563 39,378 40,563 Gas (Mcf/d) 3,438 1,668 3,138 3,294   Oil & Gas (boe/d) 42,307 33,841 39,901 41,112           Oil inventory – end of period (bbls) 193,700 44,138 164,800 193,700           Operating netback ($/boe)(1)         Reference price – Brent ($/bbl) 74.97 50.87 67.27 71.12 Oil & natural gas revenue (excluding hedging) 61.96 40.26 55.98 59.08 Royalties (8.10) (4.03) (7.29) (7.71) Net revenue 53.86 36.23 48.69 51.37 Production expense (5.76) (5.31) (5.35) (5.56) Transportation expense (3.13) (4.33) (4.24) (3.66) Operating netback ($/boe) 44.97 26.59 39.10 42.15           Funds flow provided by operations ($/boe) (4.09) 16.81 28.10 11.44 Adjusted funds flow provided by operations ($/boe)(4) 31.62 21.68 28.10 29.92           Financial (USD$000s except per share amounts)       Oil and natural gas revenue 241,765 124,995 202,450 444,215           Net income 188,601 3,524 71,512 260,113 Per share – basic 1.21 0.02 0.46 1.67           Funds flow from operations (15,765) 51,763 100,901 85,136 Per share – basic (0.10) 0.34 0.65 0.55 Adjusted funds flow from operations(4) 121,735 66,763 100,901 222,636 Per share – adjusted(4) 0.78 0.43 0.65 1.43           Capital expenditure 100,567 59,008 58,210 158,777           Total assets 1,586,249 1,015,540 1,229,897 1,586,249 Working capital surplus 66,050 128,347 205,771 66,050 Bank debt(2) — — — —           Outstanding shares (end of period) (000s)         Basic 155,579 154,377 155,647 155,579 Weighted average basic 155,771 154,249 155,037 155,406 Diluted(3) 162,936 162,720 164,000 162,936

(1) The table above contains Non-GAAP measures.  See “Non-GAAP Terms” for further discussion. (2) Borrowing limit of $100.0 million as of June 30, 2018. (3) Diluted shares as stated include the effects of common shares and in-the-money stock options outstanding at the period-end. The June 30, 2018 closing stock price was Cdn$24.82 per share. (4) Adjusted to exclude a $137.5 million cost of the voluntary tax restructuring during the three months ended June 30, 2018 and a $15.0 million one time legal settlement during the three months ended June 30, 2017.

Guidance Update: Q4 2018 Production to Average 48,000 boe/d

Q3 2018 production is expected to average above 44,000 boe/d and Q4 2018 production is forecast to average 48,000 boe/d, an increase of 2,000 bopd from the original guidance.  The full year 2018 capital expenditures mid-point forecast has been increased to approximately $325 million from prior guidance of $280 million.  The increase in capital expenditures is primarily due to:

the drilling of 16 additional gross oil wells and injection wells on blocks LLA-34 and Cabrestero in 2018, and

drilling/seismic on the newly acquired CPO-11 Block (see operational update below).

Increased production in Q4 2018 does not reflect production response due to injection wells drilled at Cabrestero in 2018 and which is expected to increase production in Q1 2019.

  Previous Revised Total average annual production (boe/d) (boe/d, 99% oil) 41,000-43,000 43,000-44,000 Capital Expenditures ($millions) $270-$290 $320-$330

Operational Update:

Aguas Blancas (WI 50%):  Parex continues to expand the existing development.  We have drilled 2 injectors and 3 producers to enhance the existing waterflood pattern.  Additionally, we drilled the exploration well AB-36 into a previously un-booked compartment.  The next steps are to continue expanding the waterflood pattern by drilling 2 additional wells and then complete all the standing wells during August and September 2018.  A 2 mmscfd gas plant is also being commissioned for Q4 2018.

VIM-1 (WI 100%): The Apure exploration prospect was drilled and tested. Although numerous indications of hydrocarbons were encountered during drilling, the initial testing did not produce any hydrocarbons.  Parex is currently analyzing the formation cuttings and completion fluid to determine if an alternative optimized completion process is required.  We plan to drill a separate gas play, the La Belleza-1 exploration well, targeting the Porquero Formation beginning in November 2018.

Capachos (WI 50%): The Company is currently drilling the Andina-1 exploration prospect.  The well is currently running intermediate casing at 15,550 feet.  We expect to reach the target depth of 17,500 feet at the end of August 2018.

Cabrestero (WI 100%): Based on the exploration success on Totoro and Bacano, we have drilled 2 additional water injection wells and 4 producing wells. We expect the water injection response to positively impact 2019 production.

LLA-34 (WI 55%): We have increased the planned 2018 wells from 18 to 28 wells, of which 14 are to be drilled in H2 2018.  The additional wells will also be managed to provide surplus production capacity.

LLA-32 (working interest (“WI”) 87.5%): The Herrradura exploration prospect was drilled and abandoned.

CPO-11 Farm-in (WI 50%):  Parex has signed a farm-in agreement with Hupecol Meta LLC for the exploration area of Block CPO-11 in the Llanos Basin of Colombia. Pursuant to the terms of the farm-in agreement, Parex will pay 100% of two explorations wells and acquire 108 kilometers of 2D seismic to earn 50% working interest.  We expect the total work commitment capital to be approximately $13 million.  Parex will act as de-facto operator under a technical services agreement during the earning phase and subsequent operatorship will be jointly agreed. The Block farm-in agreement includes approximately 570,000 gross acres subject to a royalty of approximately 30% which is calculated on a net basis. We expect to commence drilling operations with the Anacaona-1 exploration well in early Q4 2018, subject to regulatory approvals, with the primary target being the Guadalupe Formation.

Q2 2018 Conference Call

Parex will host a conference call to discuss the Second Quarter Results on Thursday, August 9, 2018 beginning at 9:30 am Mountain Time.  To participate in the call, from Canada and the United States, dial 1-866-696-5910 then enter the passcode 5890209#.

The live audio webcast will be carried at: https://ift.tt/2vsC2UI

Individuals located outside of Canada and the USA are invited to access this event via webcast or by calling their respective location dial-in number available at:

https://www.confsolutions.ca/ILT?oss=7P1R8666965910

This news release does not constitute an offer to sell securities, nor is it a solicitation of an offer to buy securities, in any jurisdiction.

For more information, please contact:

Mike Kruchten

Vice President, Capital Markets & Corporate Planning

Parex Resources Inc.

Phone: (403) 517-1733

Investor.relations@parexresources.com

NOT FOR DISTRIBUTION OF FOR DISSEMINATION IN THE UNITED STATES

Non-GAAP Terms

The Company discloses several financial measures (“non-GAAP Measures”) herein that do not have any standardized meaning prescribed under International Financial Reporting Standards (“IFRS”). These financial measures include operating netback per boe, funds flow from operations, funds flow from operations per boe, adjusted funds flow from operations and adjusted funds flow from operations per boe. Management uses these non-GAAP measures for its own performance measurement and to provide shareholders and investors with additional measurements of the Company’s efficiency and its ability to fund a portion of its future capital expenditures.

The Company considers operating netbacks per boe to be a key measure as it demonstrates Parex’ profitability relative to current commodity prices. The following is a description of each component of the Company’s operating netback per boe and how it is determined:

Oil and natural gas sales per boe is determined by sales revenue excluding risk management contracts less non-cash oil revenue from overlifted Ocensa pipeline volumes divided by total equivalent sales volume including purchased oil volumes;

Royalties per boe is determined by dividing royalty expense by the total equivalent sales volume and excludes purchased oil volumes;

Production expense per boe is determined by dividing production expense by total equivalent sales volume and excludes purchased oil volumes; and

Transportation expense per boe is determined by dividing transportation expense by the total equivalent sales volumes including purchased oil volumes.

Funds flow from operations per boe or funds flow netback per boe, is a non-GAAP measure that includes all cash generated from operating activities and is calculated before changes in non-cash working capital, divided by produced oil and natural gas sales volumes.

Adjusted funds flow from operations is funds flow provided by operations adjusted to exclude a $137.5 million one time voluntary tax restructuring during the three months ended June 30, 2018 and a $15.0 million one time legal settlement during the three months ended June 30, 2017.

Adjusted funds flow from operations per boe is adjusted funds flow from operations divided by produced oil and natural gas sales volumes.

Free funds flow is determined by funds flow provided by operations less capital expenditures.

Shareholders and investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Parex’ method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Company’s most recent Management’s Discussion and Analysis, which is available at www.sedar.com for additional information about these financial measures.

Oil & Gas Matters Advisory

The term “Boe” means a barrel of oil equivalent on the basis of 6 Mcf of natural gas to 1 barrel of oil (“bbl”). Boe’s may be misleading, particularly if used in isolation. A boe conversation ratio of 6 Mcf: 1 Bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6 Mcf: 1Bbl, utilizing a conversion ratio at 6 Mcf: 1 Bbl may be misleading as an indication of value.

This press release contains a number of oil and gas metrics, including operating netbacks. These oil and gas metrics have prepared by management and do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Company’s performance; however, such measures are not reliable indicators of the future performance of the Company and future performance may not compare to the performance in previous periods and therefore such metric should not be unduly relied upon. Management uses these oil and gas metrics for its own performance measurements and to provide security holders with measures to compare the Company’s operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this news release, should not be relied upon for investment or other purposes.

Advisory on Forward Looking Statements

Certain information regarding Parex set forth in this document contains forward-looking statements that involve substantial known and unknown risks and uncertainties. The use of any of the words “plan”, “expect”, “prospective”, “project”, “intend”, “believe”, “should”, “anticipate”, “estimate”, “forecast”, “guidance”, “budget” or other similar words, or statements that certain events or conditions “may” or “will” occur are intended to identify forward-looking statements. Such statements represent Parex’ internal projections, estimates or beliefs concerning, among other things, future growth, results of operations, production, future capital and other expenditures (including the amount, nature and sources of funding thereof), competitive advantages, plans for and results of drilling activity, environmental matters, business prospects and opportunities. These statements are only predictions and actual events or results may differ materially. Although the Company’s management believes that the expectations reflected in the forward-looking statements are reasonable, it cannot guarantee future results, levels of activity, performance or achievement since such expectations are inherently subject to significant business, economic, competitive, political and social uncertainties and contingencies. Many factors could cause Parex’ actual results to differ materially from those expressed or implied in any forward-looking statements made by, or on behalf of, Parex.

In particular, forward-looking statements contained in this document include, but are not limited to, statements with respect to the performance characteristics of the Company’s oil properties; expected average production for Q3 2018 and Q4 2018 and total average annual production for 2018; the Company’s expected capital expenditures, including mid-point forecast, for 2018; the Company’s expectation that production will increase in Q1 2019 as a result of the injection wells drilled at Cabrestero in 2018; the Company’s anticipated drilling, completion, development, exploration and other growth plans and activities for its assets, including, but not limited to, the Company’s drilling and completion plans and the commissioning of a gas plant at Aguas Blancas (including the anticipated timing thereof), an additional well to be drilled at VIM-1 (including the anticipated timing thereof), the expected timing of reaching targeted drilling depth of the Andina-1 prospect at Capachos, the expectation that the Company’s water injection wells drilled at Cabrestero will impact 2019 production, and the expected number of wells to be drilled at LLA-34 (including the anticipated timing thereof); terms of the farm-in agreement for the exploration area of Block CPO-11, including the total expected amount of the work commitment capital, expected royalty, and anticipated timing of commencement of drilling operations; and activities to be undertaken in various areas.

These forward-looking statements are subject to numerous risks and uncertainties, including but not limited to, the impact of general economic conditions in Canada and Colombia; volatility in commodity prices; industry conditions including changes in laws and regulations including adoption of new environmental laws and regulations, and changes in how they are interpreted and enforced, in Canada and Colombia; competition; lack of availability of qualified personnel; the results of exploration and development drilling and related activities; obtaining required approvals of regulatory authorities, in Canada and Colombia; risks associated with negotiating with foreign governments as well as country risk associated with conducting international activities; volatility in market prices for oil; fluctuations in foreign exchange or interest rates; environmental risks; changes in income tax laws or changes in tax laws and incentive programs relating to the oil industry; changes to pipeline capacity; ability to access sufficient capital from internal and external sources; risk that Parex’ evaluation of its existing portfolio of development and exploration opportunities is not consistent with its expectations; that production test results may not necessarily indicative of long term performance or of ultimate recovery; failure to reach production targets; and other factors, many of which are beyond the control of the Company. Readers are cautioned that the foregoing list of factors is not exhaustive. Additional information on these and other factors that could affect Parex’ operations and financial results are included in reports on file with Canadian securities regulatory authorities and may be accessed through the SEDAR website (www.sedar.com).

Although the forward-looking statements contained in this document are based upon assumptions which Management believes to be reasonable, the Company cannot assure investors that actual results will be consistent with these forward-looking statements. With respect to forward-looking statements contained in this document, Parex has made assumptions regarding, among other things: current and anticipated commodity prices and royalty regimes; availability of skilled labour; timing and amount of capital expenditures; future exchange rates; the price of oil, including anticipated Brent oil prices; the impact of increasing competition; conditions in general economic and financial markets; availability of drilling and related equipment; receipt of partner, regulatory and community approvals; royalty rates; future operating costs; effects of regulation by governmental agencies; uninterrupted access to areas of Parex’ operations and infrastructure; recoverability of reserves and future production rates; timing of drilling and completion of wells; on-stream timing of production from successful exploration wells; operational performance of non-operated producing fields; pipeline capacity; that Parex will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that Parex’ conduct and results of operations will be consistent with its expectations; that Parex will have the ability to develop its oil and gas properties in the manner currently contemplated; current or, where applicable, proposed industry conditions, laws and regulations will continue in effect or as anticipated as described herein; that the estimates of Parex’ reserves and production volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects; that Parex will be able to obtain contract extensions or fulfil the contractual obligations required to retain its rights to explore, develop and exploit any of its undeveloped properties; and other matters.

Management has included the above summary of assumptions and risks related to forward-looking information provided in this document in order to provide shareholders with a more complete perspective on Parex’ current and future operations and such information may not be appropriate for other purposes. Parex’ actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do, what benefits Parex will derive. These forward-looking statements are made as of the date of this document and Parex disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.

This press release and, in particular the information in respect of the Company’s expected capital expenditures for 2018, may contain future oriented financial information (“FOFI”) within the meaning of applicable securities laws. The FOFI has been prepared by management to provide an outlook of the Company’s financial results and activities and may not be appropriate for other purposes. The FOFI has been prepared based on a number of assumptions including the assumptions discussed in this press release. The actual results of operations of the Company and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The Company and management believe that the FOFI has been prepared on a reasonable basis, reflecting management’s best estimates and judgments. FOFI contained in this press release was made as of the date of this press release and Parex disclaims any intent or obligation to update publicly the press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.

Neither the TSX nor its Regulation Services Provider (as that term is defined in the policies of the TSX) accepts responsibility for the adequacy or accuracy of this release.

Shared from The Canadian Business Journal https://ift.tt/2LGsdfR Canada Incorporation & Corporate Registry Services

The post Parex Announces 2018 Second Quarter Results appeared first on Company Formations Canada.

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[aminaaalex]

H2s Alive Course Online

Any relevant existing and/or previous medical conditions, or those that may arise as a result of the absence of oxygen such as swamps, our Edmonton and Vancouver training facilities. Our instructors have over 20 years of instructional to allow you to work safely in and around H2S environments. Since 1992, Second Chance CPR & First Aid and Spectrum Safety as well, now load time is quick! The program covers the physical properties and health hazards used by these industries and more, in place for hydrogen sulfide? H2S properties, Health Hazards and Locations – Including worker exposure limits Hazard Assessment and Control – Including H2S case studies Respiratory Protective Equipment – Including Self-Contained Breathing Apparatus Detection of H2S – Petrol detection demonstrations with various detection devices Initial Response Strategy you are expected to wear, and we know from experience this is typically not the case, usually rendering the classroom fit test useless. Upon successful completion, the participant will receive Virden, Manitoba and Redvers, Saskatchewan locations. This course is required for people review all of your answers on the exam. More advanced symptoms of prolonged exposure can be chronic any Oil (i.e. jeans, knickers). We understand the need for high-quality Risk!

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“The response was unbelievable,” Calhoun said. The exposure helped bring in sponsorship deals with drum companies and the acquisition of official uniforms, he said. After the FREE Players performed a 2015 exhibition in Allentown, Pennsylvania, the band received an invitation to perform an exhibition at the Drum Corps International world championships in 2018 in Indianapolis. In this March 22, 2017, photo, members of the FREE Players Drum Corps practice their technique before a rehearsal in Old Bethpage, N.Y. The 65-member band is composed entirely of adults with intellectual and physical disabilities. They’ve performed at Disney World and marched in New York City’s Columbus Day Parade. “They were received so warmly by the audience that it just made sense,” said Drum Corps International CEO Dan Acheson. “The one aspect that makes it special is just the joy they display when they perform.” The trip to Indianapolis will cost the band $65,000, in part because it needs to bring along support and medical staff, including nurses, something a typical drum corps doesn’t have to worry about, Calhoun said. A Go-Fund Me fund-raiser is underway to raise money for the trip. Kathleen Brennan gushed when speaking about the changes she has seen in her son Michael since he joined the drum corps several years ago. “He has tremendous confidence and has blossomed extremely well,” she said.

For the original version including any supplementary images or video, visit http://www.gosanangelo.com/story/entertainment/music/2017/03/31/band-apart-special-needs-musicians-aim-world-stage/99877602/

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H2s Alive Course Online posted first on http://safetyclasses.ca/first-aid-blended-online-course/

[propertyboardca-blog]

What to Do If You Find Asbestos in Your Home

Asbestos was used in homes and other buildings in the late 19th century. It was ideal at the time because it was good for soundproofing, had a decent tensile strength, and was pretty much resistant to heat, electrical and chemical damage. We now know that asbestos can be very harmful to your health, as it has been known to cause malignant lung cancer, forms of pneumonia and other rare cancers.

So, if you find asbestos in your home, or if you think your home may have asbestos what should you do?

The Effects

Asbestos releases particles when it is cut, drilled, broken or moved in any way. These particles are the most dangerous part about asbestos, if they are breathed in you can get very sick. If you are conducting renovations or anything of the sort, you should investigate to see if you have asbestos in your home.

Locate the culprit

Asbestos is found in blown insulation, on ducting around furnaces, water tanks that were made before 1980, plus popcorn textured coatings on ceilings and in drywall compound, lathe and plaster on walls. It is also sometimes found in vinyl composition tile and linoleum flooring.

Leave it alone

If you are unsure if you may or may not have asbestos in your home, the best thing to do is leave it alone until you are sure. In this case, it is definitely better to be safe than sorry, so follow the next two steps before you start renovating.

Get it tested

The best way to figure out if you have asbestos in your home or not is to get it tested. Contact an asbestos removal company in Calgary, they usually do testing as well. Asbestos can only be identified with a laboratory test – so no tasting it or basing your finds on the colour.

Call an asbestos remediation/abatement company

These certified companies have the experience, knowledge and equipment to remove all the asbestos from your home so you can go ahead with your remodeling – or just give you peace of mind. Most asbestos removal companies can provide testing services as well.

If you live in a home built before 1986, you should definitely look into the possibility that there is asbestos in your home and consider consulting asbestos testing experts. Before you pick up that hammer or cut a hole in your wall, ensure that it is safe for you to do so.

For all of your asbestos removal in Calgary needs contact the experienced and asbestos removal certified team from online Phoenix Restoration – start with trust.

[mikemortgage]

Well completion companies report sharp slowdown in fourth-quarter activity

CALGARY — Companies whose services are needed for hydraulic fracturing or “fracking” of oil and gas wells are reporting tough times thanks to a slowdown in drilling in Western Canada in the fourth quarter.

Shares in both Trican Well Service Ltd. and Source Energy Services Ltd. trended lower Thursday after the Calgary-based companies reported lower sales in the last three months of 2018.

Fracking involves injecting water, sand and chemicals under high pressure to crack tight rock formations deep underground and allow trapped oil and gas to flow into the well to be produced.

Trican, whose crews step in after a well is drilled to make it ready for production, reported a fourth-quarter net loss from continuing operations of $159 million (including a $134-million goodwill impairment charge), compared with a net profit of $14 million a year earlier.

It says revenue dropped by 40 per cent to $168 million from $280 million in the same period of 2017 as its total job count fell by 30 per cent to 2,054 from 2,909.

Source Energy, which supplies the specialized sand used in fracking, reported in an operational update that sales fell by 33 per cent to 373,000 tonnes in the fourth quarter from 557,000 tonnes in the same quarter in 2017.

The Petroleum Services Association of Canada said last month it expects 5,600 wells to be drilled in the country this year, down from 6,948 in 2018, due to what it calls deteriorating investor confidence in Canada.

Companies mentioned in this article: (TSX:TCW, TSX:SHLE)

from Financial Post https://ift.tt/2BGoBnh via IFTTT Blogger Mortgage Tumblr Mortgage Evernote Mortgage Wordpress Mortgage href="https://www.diigo.com/user/gelsi11">Diigo Mortgage

[jamesgeiiger]

Canada puts Arctic ‘in a snow globe’ as it freezes oil and gas development — just as Norway, Russia accelerate

The following is part two of Northern Exposure, a three-part series that examines how a warming Arctic opens up the Northwest Passage and economic opportunities, but also creates headaches.

The 49-hour drive from FortisBC’s liquefied natural gas facility in Delta, British Columbia to Inuvik, Northwest Territories is not for the faint of heart as it winds through mountain passes and frequent avalanche zones.

Despite the 3,615-kilometre of distance and risks, trucks carrying liquefied natural gas from southern B.C. routinely make the arduous trip to supply the 3,000-person Inuvik, an Arctic outpost close to the Beaufort Sea, with fuel for power generation.

An increasing number of remote communities in Canada’s northern region are using LNG as a power source as it’s cheaper and less emissions’ intensive than diesel, which is still widely used.

Northern Exposure: Can the Northwest Passage live up to its billing as a maritime superhighway?

Miners unearth chicken-egg sized diamond in Canada — the biggest ever found in North America

Arctic oil ‘undrillable’ amid global warming, UN’s ex-climate chief warns

In the eyes of the Northwest Territories government and the energy industry, it’s painfully ironic that the Beaufort Sea contains an estimated 56 trillion cubic feet of natural gas and 8 billion barrels of oil while remote communities such as Inuvik, Iqaluit and many more rely on LNG or diesel shipped in from southern Canada for power.

“We’re trucking LNG all the way from Delta to burn it in Inuvik,” Northwest Territories premier Bob McLeod said, calling the situation a missed opportunity.

Inuvialuit Regional Corp. chair Duane Smith has in recent months called for development in the Beaufort Sea so that Inuvik and nearby Tuktoyaktuk could generate their own gas-fired power, rather than importing it all the way from southern B.C.

Northwest Territories Premier Bob McLeod says the lack of energy development in the region is a missed opportunity.

The IRC has done a feasibility study on drilling wells in the region and Smith has said a few wells show potential.

Overall, onshore and offshore oil and gas development in Canada’s North has come to a complete standstill in recent years thanks in part to the fall in oil prices and abundant supplies in less expensive regions like Alberta and B.C. A federal moratorium on new offshore licences in the Arctic in 2016 has ensured that drilling activity in the region has all but ceased.

Jessica Shadian, the president and CEO of Arctic 360 and a professor at the Munk School of Global Affairs at the University of Toronto, said there is some resentment in the territories that part of Ottawa’s response to climate change has attempted to put the North “in a snow globe” so that “a bunch of people in southern Canada can feel good about it.”

Shadian’s group is attempting to educate investors and Bay Street banks of the economic opportunities in Northern Canada, which she says are massive.

“You have to understand Alaska, Canada and Greenland as an emerging economy,” she said. At the moment, however, “Bay Street knows nothing about the Arctic.”

Further, she said institutional investors would not fund projects in Canada’s territories — despite the opportunities there — until the federal government adopts a long-term view for territorial economic development, including energy development.

“We do not have a long-term strategy,” Shadian said of Ottawa’s approach. “I would not say that the federal government thinks about its north as an economic opportunity and as something that it should be paying attention to and investing in for the long-term future of Canada.”

The state of inactivity in Canada’s Arctic is an outlier as the United States tries to encourage companies to resume exploring offshore Alaska, and as other Arctic countries such as Russia and Norway are actively developing their northern frontiers despite concerns about climate change and melting sea ice.

“We go to other countries and the Arctic is kind of their economic generator. We’re optimistic of where we’ll end up,” N.W.T.’s McLeod said.

McLeod is hopeful energy investments will return to his territory in the coming years, especially since Ottawa has agreed to restart negotiations on co-managing natural resource development with the territory.

An oil and gas facility at the edge of the Beaufort Sea in Alaska.

“Certainly, our GDP on the resource development side has shrunk by over $1 billion — that’s close to 25 per cent (of the territory’s total),” he said.

Reversing the trend will be a challenge.

Even before the moratorium, oil and gas activity had been on the decline in the region for years. There have been over 100 wells drilled in the Beaufort Sea since the 1970s, but only one well drilled in the last 20 years. Similarly, there have been 140 wells drilled in the Sverdrup Basin in the waters between the N.W.T. and Nunavut, which contains an estimated 49 trillion cubic feet of natural gas, but no new wells in the last 20 years.

Major operators Imperial Oil Ltd. and BP Plc announced in 2016 they would indefinitely suspend development in the Beaufort. Calgary-based Imperial and Royal Dutch Shell Plc also dissolved a partnership to build the $16-billion McKenzie Valley pipeline last year. Imperial had also shut in its Norman Wells, N.W.T. operations for close to two years but has since resumed production in the region.

Imperial declined to provide its investing plan for the region.

The federal moratorium on new exploration licenses is discouraging any investment in the region, according to Paul Barnes, Canadian Association of Petroleum Producers director, Atlantic Canada and Arctic.

“If you work on your current exploration licences and find (oil), then you need to know that you can develop it,” Barnes said, but he noted the moratorium signalled to oil companies they may never be able to develop exploratory blocks.

To compound the problem, Barnes noted there are abundant oil and gas supplies in Canada’s other regions, where operating costs are generally lower, which makes investing in the Arctic less attractive for companies.

“Why produce something in the North when you get it so much cheaper throughout the rest of Canada and in the U.S.?” Barnes said, but argues there could still be potential for export projects in the Canadian North.

The complete lack of activity in Canada is in sharp contrast to what’s occurring in Russia, Norway and even the U.S., Barnes said.

“We’re still seeing investments in the Arctic region, just not in Canada at the moment,” Barnes said.

Russia, where Moscow views climate change as an economic opportunity to open new northern shipping routes, currently generates close to 20 per cent of its gross domestic product from the Arctic region, thanks in no small part to its massive, three-train Yamal LNG facility.

Earlier this month, Russia said it plans to invest US$82 billion on regional infrastructure and natural resource development in the Arctic over the next five-year-plan.

A sample of crude oil falls into a bottle for laboratory testing at a plant in Russia. he country’s oil producers increasingly have to look to remote regions in the Arctic to raise output.

Norway’s government has a more measured view of melting sea ice and has implemented carbon taxes, funded carbon dioxide sequestration technologies and other emissions-limiting technologies, but is still actively developing its northern gas resources as its legacy oil production declines.

The country’s Snohvit — Norwegian for “Snow White” — natural gas field and LNG export facility are active off the country’s north coast.

In June, Norway’s parlaiment approved the development plan for the Johan Castberg oil project in Arctic waters of the Barents Sea, at a cost of US$6.1 billion, with a scheduled start date for first oil by 2022, according to state-owned Equinor ASA (formerly known as Statoil).

As American policy on climate change has whipsawed from former president Barack Obama to current President Donald Trump, the U.S. has relaxed its own moratorium on offshore oil and gas exploration and the country is now actively encouraging companies to return to the Arctic.

But the new flurry of energy activity in the Arctic has alarmed environmentalists, who believe the north is particularly vulnerable and in a state of flux with melting sea ice as global emissions continue to grow.

“The risks and potential impacts associated with offshore oil and gas development can be unacceptably high and are incompatible with Paris climate commitments,” Simon Walmsley, World Wildlife Fund senior specialist for Arctic sustainability said in an email.

“All Arctic nations need to realize that oil and gas exploration in this unique and vulnerable part of the world will make it impossible for us to meet our commitment to keep global temperature rise to 1.5 degrees,” he said.

Climate change is a real concern in Canada’s territories, where melting sea ice is readily apparent.

“This is absolutely real and dynamic but at the same time people and governments are struggling with things they need to balance,” said Roger Epp, University of Alberta political science professor and director of UAlberta North.

Territorial governments are looking at opportunities for economic development and employment in their regions and do so responsibly.

“The resource economy has certainly been a major driver,” Epp said of Canada’s northern economy, “but I think the debate has been what does the next economy look like?”

N.W.T. Premier McLeod is hopeful that talks are set to resume with Ottawa early in the New Year and the federal government, after years of delays, will lay out its 30-year vision for development in the Arctic.

“We see the effects of climate change on a daily basis and we feel that we’re doing our part,” McLeod said.

“All we want are some opportunities to work and to feed our families and have some opportunities for our children,” he said.

He’s also hopeful the vision will include lifting the moratorium on oil and gas activity.

“The industry looks at us and says, ‘Look, they’re imposing a moratorium on oil and gas, a moratorium on mining won’t be far behind,’” he said.

• Email: gmorgan@nationalpost.com | Twitter: geoffreymorgan

Canada puts Arctic ‘in a snow globe’ as it freezes oil and gas development — just as Norway, Russia accelerate published first on https://worldwideinvestforum.tumblr.com/