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Shell energy broadband is just the worst…

Royal Dutch Shell Plc .com - Sat, 10/08/2022 - 13:47

8 Oct 2022

The content below is sourced from current verifiable customer reviews of Shell Energy published on Trustpilot.

Shell energy broadband is just the WORST

Shell energy broadband is just the worst I have EVER experienced. Without broadband for 2 months (after me sending them numerous e mails with no response, obviously went with someone else!) Phone call from them 2 weeks ago asking how they could help me! Told them to go away! Phone call yesterday basically trying to bully me into paying a cancellation fee!!! It was an incredulous conversation. I told him again….politely, to go away. Got e mail 30 mins later saying they were closing the complaint. Result

Date of experience: 03 October 2022

Shell/Post Office Broadband router charge

After Shell took over Post Office Broadband I switched my provider due to terrible connection, lack of customer services and increased rates. I returned the router but they still want to charge me £35 for it and not refunding my leftover credit despite several emails and phone calls. They still keep sending me threatening emails about charging me for the unreturned router. It is dreadful and sad that an energy giant is meddling with people’s money for a few pounds

Date of experience: 09 September 2022

Why are you over charging your customers?

What a joke of a company. Since I was moved to Shell at the beginning of 2022 they have always charged me on an estimated basis even though I have been submitting meter readings every month without fail. Their customer service team are terrible and even acknowledged that they are overcharging their customers! Something needs to be done regarding their profiteering in light of the current energy crisis

Date of experience: 08 October 2022

Shell has set the minimum direct debit…

Shell has set the minimum direct debit at £103, I live alone and my monthly bill in around £70 – my account is in credit and, with the gov credit, I do not need to pay £103 a month, when I cancelled my direct debit they have said I will be charged £5 each month. They don’t care about their customers and you have to complain to get anything done.

Date of experience: 07 October 2022

The worst company i ever had they…

The worst company i ever had they stolen my money they open 2 account on my name on my proveisly adress when i not living over 2 years and won’t give me back please ppl be careful with them i been call them so meny times and they ignore me

Date of experience: 08 October 2022


As a Shell Energy customer original service fine but after upgrade to 3 phase meter (to allow additional solar panels) ordered 3 phase meter to have installation cancelled at last minute. Raised complaint to customer services and after multiple twitter DM contacts over 2 months on I am not one step closer to understanding when it will be installed. This is now impacting my self build project. Millions of promises and almost zero feedback. Just had third email to say I need to update details of my phone number when I have already replied twice before.

Date of experience: 08 October 2022

Still no word…

Still no word on the resolution to the IHD not working since April.

Usage information fails to load on App and yet they want to charge more! For what service am I paying?

Breach of contract?


Date of experience: 05 October 2022

After blue planet busted I was put with…

After blue planet busted I was put with this bad company, I paid my direct debit of £250 a month, but built up a £2000 debt over the year. They then decided without notification to take £800 from my account and then would not let me set my direct debit lower than £800, despite my electric consumption now being about £150 a month. I cancelled the direct debit and started paying them £350 a month which is more than I am using and will clear the excess in 6 months or so, but that’s not good enough for them, they are sending snotty emails demanding the £1200 now or my credit will be affected. I am currently in a monopoly with shell and they can charge what ever they like as I have no alternative, but trust me, the second I can leave them, I will be gone NEVER to use them again, not even road fuel….

Date of experience: 08 October 2022

The above are extracts from negative customer reviews about Shell Energy posted during the last few days on Trustpilot.  Visit the Shell Energy page on Trustpilot to view all reviews in their entirety, positive and negative (and Shell Energy responses). Watch out for any fake reviews. Note the reoccurring themes in the negative reviews, including difficulty in communicating with the company. Shell Plc CEO Ben Van Beurden openly admitted at the Shell AGM held in London on 23 May 2022 that all is not well at Shell Energy. 

Shell energy broadband is just the worst… was first posted on October 8, 2022 at 9:47 pm.
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Natural Gas Forwards Mixed, but Market Shows Signs of Shaking Off Shoulder Season Doldrums

NGI Shale Daily - Thu, 10/06/2022 - 14:20

With the market preparing to turn its attention to the start of winter heating demand, natural gas forwards at numerous Lower 48 hubs posted modest gains during the Sept. 29-Oct. 5 trading period, NGI’s Forward Look data show. 

Despite a small discount at benchmark Henry Hub, which shed 3.0 cents to $6.935/MMBtu, prices for November delivery climbed at a number of demand hubs. Strengthening in November basis differentials was widespread, including trading locations in the Northeast, Appalachia, Midwest and Rockies.

In New England, Algonquin Citygate basis climbed to plus $4.138 for November delivery, a 16.1-cent swing higher for the period. 

[Is it really an energy transition? Liberty Energy CEO Chris Wright explains why he thinks robust natural gas demand will endure and why the “energy transition,” in his view, is not really a transition at all – but rather a gradual shift to more varied sources of energy that could take centuries to fully develop. Listen to NGI’s Hub & Flow podcast now.]

In the Midwest, Chicago Citygate basis added 14.8 cents for November, ending 37.6 cents back of the national benchmark.

Several Appalachian hubs posted even stronger basis gains, including Eastern Gas South, where November basis rallied 30.2 cents week/week to minus 91.1 cents.

Out west in the Rockies, Cheyenne Hub narrowed the gap to Henry to minus 65.3 cents, an 11.7-cent gain.

Why Are Bulls ‘Buying The Dip’?

Meanwhile, after selling off sharply in recent weeks, Nymex futures showed signs of establishing a shoulder-season bottom during the period, a stretch that notably included a 36.7-cent rally in Tuesday’s session.

Traders shrugged off a hefty triple-digit storage build on Thursday to push the November contract another 4.2 cents higher to $6.972, just shy of the $7 mark. 

Still, the Energy Information Administration’s (EIA) latest report, a whopping 129 Bcf injection for the week ended Sept. 30, served to temper the bullish case. 

The print far outpaced the 87 Bcf five-year average, pushing stockpiles to 3,106 Bcf and cutting the year-on-five-year deficit to minus-7.8% as of Sept. 30, EIA data show. 

In terms of factors potentially putting upward pressure on prices Thursday, “immediate-term gas demand will rise into the weekend, technicals are supportive of extended gains and seasonal upside risks outweigh downside,” according to EBW Analytics Group analyst Eli Rubin.

Storage builds over the next few weeks, though, are poised to shrink the deficit to the five-year average, the analyst said. This coupled with a “lack of cold weather may postpone attempts for Nymex gas to breakout to the upside.”

NatGasWeather said next week’s reported build “could be even larger than today’s, potentially climbing into the 130s Bcf.” With domestic production reaching record highs, “the supply/demand balance isn’t as scary as market participants were looking at a few months ago.”

And yet, “this hasn’t stopped bulls from again buying the dip,” the firm added.

The recent move higher might reflect technical or seasonal factors, or it might reflect “expectations U.S. and global supplies will tighten considerably this winter season,” NatGasWeather said. 

Those holding such supply adequacy concerns “must be looking forward” given that “U.S. supplies will have increased more than 600 Bcf in just six weeks, smashing the previous fall shoulder season injection record,” NatGasWeather added.

Winter Risks For Europe

Looking overseas, with winter approaching in the northern hemisphere, natural gas markets in Europe have reason to feel “snug but by no means cozy,” according to a recent note from Rystad Energy vice president Emily McClain.

Recent damage to the Nord Stream 1 and 2 pipelines has further tightened global natural gas supply, the analyst noted.

“Europe’s gas market participants are now looking to storage injections to safeguard inventories through winter,” McClain said. “However, while European storage levels are shaping up nicely, an early or extended winter could yet send gas stocks sledding downward, pushing prices higher.”

As for Asia, with high storage levels “expected to last through December, most market focus has now shifted to January LNG imports,” McClain added. 

Permian Basis Slips

Meanwhile, looking at regional trends in the domestic market, pipeline disruptions served to pressure Permian Basin forward prices lower during the Sept. 29-Oct. 5 period.

El Paso Permian basis for November delivery tumbled 25.0 cents lower, ending at minus $3.146, while Waha fell 20.6 cents to minus $3.201.

Wood Mackenzie reported a number of pipeline events impacting the Permian region during the period, including a force majeure on the El Paso Natural Gas (EPNG) system on its Line 1300 that was expected to impact roughly 180,000 MMBtu/d of flows.

EPNG was also scheduled to reduce westbound flows on its Line 1100 for maintenance starting Monday and continuing through Oct. 21, according to the firm.

The post Natural Gas Forwards Mixed, but Market Shows Signs of Shaking Off Shoulder Season Doldrums appeared first on Natural Gas Intelligence

Natural Gas Forward Curves Retreat as Deadly Ian Rages Across Southeast

NGI Shale Daily - Fri, 09/30/2022 - 12:49

With natural gas production remaining stout – even amid temporary shut-ins ahead of Hurricane Ian – and cooler weather leaving its mark on storage inventories, natural gas forward prices continued to fall during the Sept. 22-28 week, according to NGI’s Forward Look.

In the latter part of the period, all attention was on Florida, where Ian packed maximum sustained winds around 150 mph when it made landfall on the southwest coast near Cayo Costa Wednesday afternoon.

The system was downgraded to a tropical storm on Thursday but regained hurricane status by early Friday. Ian made a second landfall as a category 1 hurricane near Georgetown, SC, Friday afternoon.

About one million Florida utility customers remained without power as of Friday afternoon, with more outages likely along Ian’s path. The storm killed more than 20, and the death toll was expected to climb substantially. Thousands of residents were unaccounted for Friday, according to the Florida governor’s office.

The National Hurricane Center (NHC) said on the forecast track, after landfall Ian would move farther inland across eastern South Carolina and central North Carolina Friday night and Saturday. Ian should dissipate over western North Carolina or Virginia late Saturday.

The governors of North and South Carolina, Virginia and Georgia declared states of emergency in their respective states.

Chevron Corp. and BP plc shut in offshore platforms ahead of Ian, but had begun redeploying offshore personnel and restarted production by Thursday. On Friday, early data pointed to output that was back near recent highs.

October forward prices at Florida Gas Zone 3 – which includes transactions east of Compressor Station 8 in East Baton Rouge Parish, LA, through the end of Zone 3 in Santa Rosa County, FL – came off 43.0 cents to average $7.214/MMBtu for the period through Wednesday, according to Forward Look. This compared with a 22.0-cent decline at the Henry Hub, thereby tightening Zone 3’s premium over the benchmark to 33.5 cents, compared to 60.8 cents a week earlier.

A similar basis contraction was seen for the winter strip (November-March), where Zone 3’s premium tumbled to 37.6 cents from 84.2 cents last week. The five-month package settled Wednesday at $7.657. Basis pricing for next summer (April-October) was stable at 51.0 cents, with fixed prices for the strip averaging $5.400.

Weakening in basis pricing also was seen at Transco Zone 5, which begins at the South Carolina/Georgia border and ends at the Maryland/Virginia border just northeast of Station 185. October prices as of Wednesday stood at $4.500, a roughly $2.38 discount to Henry Hub, Forward Look data showed. A week ago, that discount was $1.855. Notably, the winter strip was down by more than 50 cents on the week but still averaged a plump $10.182. The summer 2023 strip averaged only $3.890.

‘Long, Challenging’ Road To Recovery

There is risk for more downside ahead given Ian’s devastating impact and the potentially long recovery ahead.

Florida Power & Light Co. (FPL), the largest electric utility in the state, had restored power to more than one million – or just over 50% – of its customers by Friday morning. As FPL begins assessing the far-reaching damage, the company expects some customers to face prolonged outages because portions of the electric system in Southwest Florida need to be rebuilt rather than repaired.

“Hurricane Ian has forever altered the lives of so many of our fellow Floridians and we recognize the road to recovery will be long and challenging,” said CEO Eric Silagy. “We understand how difficult it is to be without power, and our dedicated men and women will continue to work around the clock until every customer’s electricity is back on. That said, the catastrophic nature of this storm means that we may need to rebuild parts of our system in Southwest Florida, which will take time.”

Duke Energy Florida also had made headway into its restoration efforts, with 650,000 customers restored by Friday afternoon. About 430,000 customers were still without power.

EBW Analytics Group said any delayed restoration of the electric grid in Florida could lead to protracted gas demand destruction lasting multiple weeks, although volumes may be increasingly small. By contrast, near-term demand destruction is set to rise this weekend as Ian’s second landfall extends the cumulative destructive toll. 

Het Shah of Analytics.AI agreed the impact to gas demand may be not as significant had the storm landed at the peak of summer. He noted that Florida natural gas consumption in September is between 4.5-5.0 Bcf/d on average, with power burns making up roughly 90% of the gas consumption.

“We also need to remember that this number is front loaded with more cooling degree days at the beginning of the month. So for the last few days of the month, power burn should be roughly 3.8 Bcf/d with normal temperatures,” Shah said. “Assuming 24% of customers are out of power as of Thursday, that equates to 0.9 Bcf/d at the peak.”

Demand should start to recover as power is restored across Florida, according to Shah. “The question still remains on how long it takes to restore power, so some unknowns remain.”

Warm October Forecast

Beyond storm activity, October is expected to be warmer than normal, offering a catalyst for prices to move lower. Independent forecaster DTN’s outlook favors extensive warming across the central United States, leading to a most-likely forecast of only 223 gas-heating degree days (gHDD), which is 25 gHDDs below 10-year normals.

The bearish near-term outlook enables injections to potentially reach into the 120s Bcf per week, according to EBW. Still, the late-October forecast is subject to extensive variability.

“While it is too early in the season to generate substantial heating demand, weather models have cooled in the Northeast” over the past couple of days, EBW senior analyst Eli Rubin said. “If cold builds and November cracks resistance near $7.14/MMBtu, a notable near-term upswing is favored.”

For now, the projected warmth should continue to chip away at the lingering storage deficit. Recent inventory data suggest production growth and declining demand already have had an impact on stocks.

Adding to the bearish picture, Cove Point LNG is scheduled to go offline over the weekend for planned maintenance. The three-week turnaround would trim 800,000 Mcf/d off demand, and potentially shift this gas into storage.

Storage crunch fears for the upcoming winter are dissipating, with recent storage data showing some improvement in inventories.

The Energy Information Administration (EIA) on Thursday reported the second consecutive triple-digit injection into underground storage. The 103 Bcf build matched the prior week’s build and trimmed the deficit to the five-year average by 26 Bcf week/week.

The latest inventory stat surprised the market once again, with consensus ahead of the EIA report in the low to mid-90s Bcf.

In the comparable week last year, EIA reported an injection of 86 Bcf. The five-year average is 77 Bcf.

Broken down by region, the Midwest led with a 35 Bcf increase to stocks, while the East added 31 Bcf, according to EIA. South Central inventories rose by 23 Bcf, which included an 18 Bcf injection into nonsalt facilities and a 5 Bcf build in salts.

Total working gas in storage as of Sept. 23 was 2,977 Bcf, which is 180 Bcf below year-ago levels and 306 Bcf below the five-year average, EIA said.

Looking ahead to the agency’s next report, for the week ending Sept. 30, Shah said he’s modeling “a really small impact” because of only two days of hurricane impact. This would equate to roughly 2-3 Bcf of demand destruction.

“My current storage estimate is 121 Bcf for the week ending Sept. 30,” Shah said. “For week ending Oct. 6, we are likely to have some demand destruction throughout the week even with crews ready to get power infrastructure back up. So roughly 5-7 Bcf of demand destruction.”

Lingering Winter Supply Concerns

Despite the larger storage builds of late, deficits have proven to be rather sticky, and the forward curve shape reflects an appropriate concern of insufficient winter supply, according to Mobius Risk Group.

The October contract, fell by more than $2 in less than two weeks’ time, held a roughly 74-cent premium to the March contract when it rolled off the board. October also expired at a $1.91 premium to the October 2023 contract.

“With such a dramatic decline in a brief period of time, it is rational to consider what fundamental changes may be prompting the change in flat price,” said Mobius gas analyst Zane Curry. “However, curve shape is often a better indicator of fundamental conditions.”

He noted that the February contract remained almost $1.00 over March, which held a $1.23 premium to April. “Fall demand weakness is a factor, but not necessarily a reason to believe explosive winter upside is off the table.”

Harping down on recent volatility, Curry noted that the winter strip has been under intense pressure of late. As of Wednesday’s close, the strip priced at around $6.940.

“Over the past month the upcoming winter withdrawal season peaked at $9.34, and the round trip since just after the Fourth of July has been prolific,” he said. “…We have seen this tenor travel more than $6.00 in less than three months.”

The November Nymex gas futures contract settled Friday at $6.766, down 10.8 cents from Thursday’s close.

The post Natural Gas Forward Curves Retreat as Deadly Ian Rages Across Southeast appeared first on Natural Gas Intelligence


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