News Feed Item

Storm Resources Ltd. ("Storm" or the "Company") is Pleased to Announce Its Financial and Operating Results for the Three Months Ended March 31, 2014

CALGARY, ALBERTA -- (Marketwired) -- 05/14/14 -- Storm Resources Ltd. (TSX VENTURE: SRX)

Storm has also filed its unaudited condensed interim consolidated financial statements as at March 31, 2014 and for the three months then ended along with Management's Discussion and Analysis ("MD&A") for the same period. This information appears on SEDAR at www.sedar.com and on Storm's website at www.stormresourcesltd.com.

Selected financial and operating information for the three months ended March 31, 2014, appears below and should be read in conjunction with the related financial statements and MD&A.


                                                Three Months   Three Months
Thousands of Cdn$, except volumetric                   Ended          Ended
and per-share amounts                         March 31, 2014 March 31, 2013

  Gas sales                                           12,017          3,047
  NGL sales                                            5,511          1,579
  Oil sales                                            3,279          4,422
Revenue from product sales(1)                         20,807          9,048

Funds from operations(2)                               8,660          3,227
  Per share - basic ($)                                 0.09           0.05
  Per share - diluted ($)                               0.08           0.05
Net income (loss)                                        206           (261)
  Per share - basic ($)                                 0.00           0.00
  Per share - diluted ($)                               0.00           0.00
Operations capital expenditures                       22,343         20,133
Acquisitions and dispositions                         88,051        (19,496)
Debt including working capital deficiency             22,176         42,106
Weighted average common shares outstanding
  Basic                                              100,668         61,824
  Diluted                                            102,413         61,824
Common shares outstanding (000s)
  Basic                                              109,612         61,824
  Fully diluted                                      115,251         65,791

Oil equivalent (6:1)
  Barrels of oil equivalent (000s)                       456            224
  Barrels of oil equivalent per day                    5,068          2,488
  Average selling price (Cdn$ per Boe)(1)              45.62          40.37
Gas Production
  Thousand cubic feet (000s)                           2,134            880
  Thousand cubic feet per day                         23,711          9,780
  Average selling price (Cdn$ per Mcf)                  5.63           3.46
NGL production
  Barrels (000s)                                          65             24
  Barrels per day                                        725            261
  Average selling price (Cdn$ per barrel)              84.49          67.08
Oil Production
  Barrels (000s)                                          35             54
  Barrels per day                                        391            597
  Average selling price (Cdn$ per barrel)(1)           93.08          82.21
Wells drilled
  Gross                                                  5.0            3.0
  Net                                                    5.0            2.6
(1) Excludes hedging gains and losses.
(2) Funds from operations and funds from operations per share are non-GAAP
    measurements. See discussion of Non-GAAP Measurements on page 9 of the
    MD&A and the reconciliation of funds from operations to the most
    directly comparable measurement under GAAP, "Cash Flows from Operating
    Activities", on page 19 of the MD&A.

President's Message


--  Production in the first quarter was 5,068 Boe per day (22% oil plus
    NGL), an increase of 104% from the same period last year and 6% from the
    prior quarter. On a per-share outstanding at quarter end basis, the
    year-over-year increase was 15%. The increase resulted from growth at
    Umbach where first quarter production was 3,559 Boe per day which
    represents growth of 565% from the first quarter of 2013.

--  NGL production was 725 barrels per day in the first quarter, a year-
    over-year increase of 178%. NGL production increased as a result of
    production growth from the liquids-rich Montney formation at Umbach. The
    first quarter NGL price of $84.49 per barrel was 84% of the average
    Edmonton Par light oil price.

--  Activity in the first quarter of 2014 was focused on Storm's 100%
    working interest lands at Umbach South where four Montney horizontal
    wells (4.0 net) plus one Montney vertical delineation well (1.0 net)
    were drilled and two horizontal wells (2.0 net) were completed and
    pipeline connected. As the existing facility is at capacity, only one of
    the completed Montney horizontal wells started producing in late
    February with the average rate in March and April being restricted to
    4.3 Mmcf per day gross raw gas. The remaining Montney horizontal wells
    will start producing in September when Storm's new facility at Umbach is

--  Funds from operations for the quarter totaled $8.7 million or $0.09 per
    basic share, a year-over-year increase of 80% on a per-share basis. The
    increase in funds from operations was the result of growth at Umbach
    where the field operating netback was $27.03 per Boe which is higher
    than the corporate average.

--  The funds from operations netback was $18.99 per Boe in the quarter, an
    increase of $4.58 per Boe or 32% from the prior year. The year-over-year
    improvement was primarily the result of lower operating costs and the
    first quarter natural gas price increasing to $5.63 per Mcf from $3.46
    per Mcf in the prior year period. These gains were partially offset by a
    hedging loss of $3.10 per Boe.

--  The field operating netback, excluding hedging gains or losses, was
    $25.47 per Boe for the quarter, an increase of 26% from $20.14 per Boe
    in the previous year. The first quarter operating cost was $10.88 per
    Boe, a decrease of 20% from the prior year. Operating costs are
    improving due to growth at Umbach where the first quarter operating cost
    was $7.78 per Boe.

--  Controllable cash costs (operating, transportation, cash G&A, interest
    expense) were $15.97 per Boe in the quarter which is a decrease of $4.84
    per Boe, or 23%, from $20.81 per Boe in the prior year.

--  Capital investment was $110.4 million in the first quarter which
    included $88.0 million for an asset acquisition at Umbach. Operations
    capital expenditures totaled $22.3 million and included $3.4 million for
    facilities and pipelines plus $17.8 million for drilling and

--  Debt plus working capital deficiency, net of investments, at the quarter
    end totaled $22.2 million which is 0.6 times annualized first quarter
    cash flow. In May 2014, Storm's banker, ATB Financial, increased the
    revolving bank facility to $90.0 million.

--  On January 31, Storm closed the acquisition of a 100% working interest
    in 29 sections of land in the Umbach-Nig area, prospective for liquids-
    rich natural gas from the Montney formation. The acquisition included
    two horizontal wells producing 359 Boe net per day (19% NGL) from the
    Montney formation. The total cost of approximately $88.0 million
    consisted of $30.0 million in cash and 13.6 million common shares of
    Storm with a deemed value of $4.25 per common share (closing price on
    the TSX Venture Exchange January 30, 2014).

--  On February 14, a bought deal financing and non-brokered private
    placement of common shares were completed with 8.5 million common shares
    being issued at a price of $4.10 per common share. Aggregate gross
    proceeds of $34.9 million were used to fund the cash portion of the
    acquisition of land and production in the Umbach-Nig area that closed
    January 31, 2014.


Storm has a focused asset base with large land positions in resource plays at Umbach and in the Horn River Basin ("HRB") which have multi-year drilling inventories while the Grande Prairie area, with its shallow decline, provides cash flow available for investment.

Umbach, Northeast British Columbia

Storm's land position at Umbach is prospective for liquids-rich natural gas from the Montney formation and currently totals 140 net sections (168 gross sections), or 98,000 net acres. Including the lands acquired in January 2014, Storm has invested $108.0 million to acquire this land position ($2,750 per hectare or $1,100 per acre) since entering the area in 2010. There are three project areas at Umbach:

--  Umbach South with 87 net sections at a 100% working interest (includes
    the 29 sections recently acquired) where first quarter production
    averaged 2,676 Boe per day;

--  Umbach North with 33 net sections of jointly owned lands (61 gross
    sections with Storm's working interest being 60% on most of the lands)
    where first quarter production averaged 883 Boe per day;

--  Nig with 20 net sections at a 100% working interest.

To date, Storm has been focused on exploiting the upper Montney, although the middle and lower Montney may also be productive.

First quarter production at Umbach was 3,559 net Boe per day (18% NGL), a year-over-year increase of 565%. NGL recovery was 38 barrels per Mmcf sales or 656 barrels per day with approximately 60% being higher priced condensate plus pentanes. The operating netback was $27.03 per Boe with revenue, after deducting transportation costs, of $42.32 per Boe ($5.56 per Mcf sales and $81.65 per barrel of NGL), a royalty rate of 18%, and operating costs of $7.78 per Boe. Operating costs at Umbach have improved significantly from $11.48 per Boe in the first quarter of 2013. Notably, on the 100% working interest lands at Umbach South where Storm owns field compression, the operating cost was $6.55 per Boe.

Activity in the first quarter included drilling four Montney horizontal wells (4.0 net) at Umbach South, drilling one Montney vertical delineation well (1.0 net) at Nig and completing two Montney horizontal wells (2.0 net). One Montney horizontal well commenced production in late February with the rate being restricted to 4.3 Mmcf per day gross raw gas in March and April as the existing facility is full. This horizontal well has averaged 6.0 Mmcf per day gross raw gas to date in May as a result of facility upgrades completed in early May. The vertical delineation well at Nig was cored in the upper, middle, and lower Montney and, after the core data has been analyzed, the wellbore will be re-entered and a horizontal well will be drilled into one of the three Montney intervals (likely in 2015). To date in the second quarter, an additional three Montney horizontal wells (3.0 net) have been drilled and two Montney horizontal wells (2.0 net) have been completed.

The existing Umbach South field compression facility has been full since December 2013 with throughput of approximately 17 Mmcf per day gross raw gas. As a result, a second field compression facility is being constructed with initial capacity of 24 Mmcf per day which is expected to be operational in September 2014. Cost of the new field compression facility is $14.0 million and it is designed to be expandable to 48 Mmcf per day for an additional investment of $9.0 million, with this expected to occur in mid-2015. Investment in infrastructure at Umbach in 2014 will also include installing 12 kilometers of larger diameter gathering pipelines at a cost of $5.0 million.

Currently, there are 16 horizontal wells producing from the Montney formation at Umbach. Production performance of the most recent horizontal wells (Umbach South hz's 10 - 15) is significantly improved from earlier wells and is exceeding management's forecasts. Following is a comparison of calendar day rates for all of the producing Montney horizontal wells.

                                                    30 Cal   90 Cal 1st Year
                                                       Day      Day  Cal Day
                                                     Gross    Gross    Gross
             Working            Start of     Frac Raw Mmcf Raw Mmcf Raw Mmcf
            Interest          Production   Stages  Per Day  Per Day  Per Day
Hz's 1 - 5        60%  Umbach   Mar/11 -   7 - 11      2.8      1.8      1.3
                        North     Oct/12            Mmcf/d   Mmcf/d   Mmcf/d
                                                    5 hz's   5 hz's   5 hz's
Hz's 6 - 8        60%  Umbach   Nov/12 -  14 - 16      3.3      2.3      1.5
                        North     Aug/13            Mmcf/d   Mmcf/d   Mmcf/d
                                                    3 hz's   3 hz's   2 hz's
Hz's 10 - 15     100%  Umbach   Apr/13 -  17 - 18      4.2      3.6      2.8
                        South     Nov/13            Mmcf/d   Mmcf/d   Mmcf/d
                                                    6 hz's   5 hz's     1 hz

Horn River Basin, Northeast British Columbia

Storm has a 100% working interest in 123 sections in the HRB (81,000 net acres) which is prospective for natural gas from the Muskwa, Otter Park and Evie/Klua shales. First quarter production averaged 380 Boe per day at an operating netback of $17.03 per Boe. Production is from one horizontal well with 12 fracture stimulations which currently produces 2.5 Mmcf per day gross raw gas with cumulative production of 4.0 Bcf gross raw gas since start-up in March 2011.

A resource evaluation completed by InSite Petroleum Consultants Ltd. effective December 31, 2011 estimates that the best estimate of DPIIP in the core producing area is 3.1 Tcf gross raw gas with the best estimate of contingent resources being 616 Bcf. The evaluated area includes 30 sections at a 100% working interest and represents 24% of Storm's total land holdings in the HRB. Commerciality has been proven across the core producing area with a horizontal well that has been producing for 38 months plus two vertical wells that were completed and tested with final test rates of 900 Mcf per day over the final 24 hours of each flow test.

Grande Prairie Area, Northwest Alberta and Northeast British Columbia

Production in the first quarter averaged 1,129 Boe per day (41% oil plus NGL) at an operating netback of $23.43 per Boe. Production was reduced by approximately 115 Boe per day as a result of equipment failures on seven wells. The cost of repairing the wells increased the first quarter operating cost to $21.10 per Boe (2013 average operating cost was $14.72 per Boe). Production in April recovered to 1,260 Boe per day based on field estimates. Cash flow from this area continues to be re-invested to grow production at Umbach.


Current commodity price hedges, which comprise both swaps and collars, for the remainder of 2014 include 11,800 Mcf per day (14,200 GJ per day) of natural gas with an average floor price of approximately $4.16 per Mcf and an average ceiling price of $4.38 per Mcf (AECO monthly index $3.38 per GJ for the floor and $3.56 per GJ for the ceiling). In addition, an oil price of WTI Cdn$102.43 per barrel (WTI price in $US per barrel converted to $Cdn per barrel) has been fixed on 450 barrels per day.

In the first quarter of 2015, the price of 5,800 Mcf per day (7,000 GJ per day) of natural gas has been hedged with an average floor price of approximately $4.92 per Mcf and an average ceiling price of $6.25 per Mcf (AECO monthly index $4.00 per GJ for floor and $5.08 per GJ for ceiling).

The purpose of Storm's commodity price hedges is to ensure that a decrease in commodity prices does not have a significant impact on capital investment and growth over the next 12 to 18 months.


Production in April averaged 5,350 Boe per day based on field estimates, and second quarter production is forecast to be 5,200 to 5,500 Boe per day. Corporate production will increase when the new field compression facility is operational at Umbach in September 2014.

As a result of a higher forecast natural gas price and the recent changes to British Columbia's Deep Well Royalty Credit Program, Storm is increasing 2014 capital investment from $78.0 million to $97.0 million. The incremental capital will be invested at Umbach to drill an additional four Montney horizontal wells (4.0 net) and complete four Montney horizontal wells (3.6 net). Forecast production for the fourth quarter of 2014 increases to 8,900 to 9,200 Boe per day which represents 90% growth on a year-over-year basis (55% growth on a per-share basis). Revised guidance is set forth below.

                                     January 23, 2014          May 14, 2014
                                    Original Guidance      Revised Guidance
AECO natural gas price                   $3.35 per GJ          $4.25 per GJ
Edmonton Par light oil price          Cdn $89 per bbl       Cdn $94 per bbl
Estimated year-end debt plus
 working capital deficiency(1)          $50.0 million         $57.0 million
Estimated average operating
 costs                          $8.00 - $9.00 per Boe $8.00 - $9.00 per Boe
Estimated average royalty rate
 (on production revenue before
 hedging)                                    14% - 15%             15% - 16%
Estimated operations capital,
 excluding acquisitions &
 dispositions                           $78.0 million         $97.0 million
Estimated acquisitions                  $88.0 million         $88.0 million
Estimated cash G&A net of
 recoveries                              $4.0 million          $4.0 million
Forecast fourth quarter average
 production                       7,500 - 7,900 Boe/d   8,900 - 9,200 Boe/d
                                       (20% oil + NGL)       (20% oil + NGL)
Forecast average annual
 production                       5,500 - 6,500 Boe/d   6,000 - 6,700 Boe/d
                                       (21% oil + NGL)       (21% oil + NGL)
Umbach horizontal wells drilled    10 gross (10.0 net)   14 gross (14.0 net)
Umbach horizontal wells
 completed & tied in                 9 gross (9.0 net)   13 gross (12.6 net)

(1) Includes value of publicly listed securities.

Adjusted net debt at the end of 2014 is forecast to be $57.0 million (including public company investments), which would be approximately 0.9 times annualized funds from operations in the fourth quarter of 2014 (assumes fourth quarter AECO $3.75 per GJ and Edmonton Par Cdn$87.00 per barrel).

The recently announced changes to British Columbia's Deep Well Royalty Credit Program provides a royalty credit of approximately $0.6 million for a Montney horizontal well with a 1,200 metre lateral drilled at Umbach after April 1, 2014. The royalty credit reduces the royalty rate to 6% until the credit is used up which is forecast to be approximately 14 months at an AECO natural gas price of $3.75 per GJ. Eight of Storm's Montney horizontal wells being drilled at Umbach in 2014 will benefit from the royalty credit which will be re-invested to drill and complete additional horizontal wells at Umbach.

At Umbach, one drilling rig has been working since early December 2013 and has drilled eight Montney horizontal wells (8.0 net) with seven horizontal wells drilled as part of the 2014 program. Drilling operations have continued through spring break-up and the remaining seven Montney horizontal wells (7.0 net) in the 2014 program are expected to be drilled by the end of August. Four Montney horizontal wells (4.0 net) have been completed so far in 2014 with one well commencing production in late February. Horizontal well performance is exceeding management's forecast which has moderated declines. As a result, the existing facility is full and most of the newly drilled Montney horizontal wells will commence production once construction of the new 24 Mmcf per day field compression facility is completed in September 2014. The decision to expand the new facility to 48 Mmcf per day

will likely be made in the fourth quarter of 2014 with approximately six to eight months being required to order equipment and for construction of the expansion. With a growing inventory of horizontal wells to be turned on when the second field compression facility is completed, significant growth is expected at Umbach in the second half of 2014.

Storm's land position in the HRB continues to be a core, long-term asset with significant leverage to improving natural gas prices.


Brian Lavergne, President and Chief Executive Officer

May 14, 2014

Discovered-Petroleum-Initially-in-Place ("DPIIP") - is defined in the Canadian Oil and Gas Evaluation Handbook ("COGEH") as the quantity of hydrocarbons that are estimated to be in place within a known accumulation. DPIIP is divided into recoverable and unrecoverable portions, with the estimated future recoverable portion classified as reserves and contingent resources. There is no certainty that it will be economically viable or technically feasible to produce any portion of this DPIIP except for those portions identified as proved or probable reserves.

Contingent Resources - are those quantities of petroleum estimated, as of a given date, to be potentially recoverable from known accumulations using established technology or technology under development, but which are not currently considered to be commercially recoverable due to one or more contingencies. Contingencies may include factors such as economic, legal, environmental, political and regulatory matters, or a lack of markets. It is also appropriate to classify as contingent resources the estimated discovered recoverable quantities associated with a project at an early stage of development. Estimates of contingent resources are estimates only; the actual resources may be higher or lower than those calculated in the independent evaluation. There is no certainty that the resources described in the evaluation will be commercially produced.

Boe Presentation - For the purpose of calculating unit revenues and costs, natural gas is converted to a barrel of oil equivalent ("Boe") using six thousand cubic feet ("Mcf") of natural gas equal to one barrel of oil unless otherwise stated. Boe may be misleading, particularly if used in isolation. A Boe conversion ratio of six Mcf to one barrel ("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. All Boe measurements and conversions in this report are derived by converting natural gas to oil in the ratio of six thousand cubic feet of gas to one barrel of oil. Mboe means 1,000 Boe.

Forward-Looking Information - This press release contains forward-looking statements and forward-looking information within the meaning of applicable securities laws. The use of any of the words "will", "expect", "anticipate", "intend", "believe", "plan", "potential", "outlook", "forecast", "estimate" and similar expressions are intended to identify forward-looking statements or information. More particularly, and without limitation, this press release contains forward-looking statements and information concerning: production; drilling plans; reserve volumes; capital expenditures; royalties; financing; commodity prices; and production, operating and general and administrative costs.

The forward-looking statements and information in this press release are based on certain key expectations and assumptions made by Storm, including: prevailing commodity prices and exchange rates; applicable royalty rates and tax laws; future well production rates; reserve and resource volumes; the performance of existing wells; success to be expected in drilling new wells; the adequacy of budgeted capital expenditures to carrying out planned activities; the availability and cost of services; and the receipt, in a timely manner, of regulatory and other required approvals. Although the Company believes that the expectations and assumptions on which such forward-looking statements and information are based are reasonable, undue reliance should not be placed on these forward-looking statements and information because of their inherent uncertainty. In particular, there is no assurance that exploitation of the Company's undeveloped lands and prospects will result in the emergence of profitable operations.

Since forward-looking statements and information address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to the risks associated with the oil and gas industry in general such as: operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to reserves, production, costs and expenses; health, safety and environmental risks; commodity price and exchange rate fluctuations; marketing and transportation of petroleum and natural gas and loss of markets; environmental risks; competition; ability to access sufficient capital from internal and external sources; stock market volatility; and changes in legislation, including but not limited to tax laws, royalty rates and environmental regulations.

Readers are cautioned that the foregoing list of factors is not exhaustive. Additional information on these and other factors that could affect the operations or financial results of the Company are included or are incorporated by reference in the company's MD&A for the three months ended March 31, 2014.

The forward-looking statements and information contained in this press release are made as of the date hereof and the Company undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws.


Storm Resources Ltd.
Brian Lavergne
President & CEO
(403) 817-6145

Storm Resources Ltd.
Donald McLean
Chief Financial Officer
(403) 817-6145

Storm Resources Ltd.
Carol Knudsen
Manager, Corporate Affairs
(403) 817-6145

More Stories By Marketwired .

Copyright © 2009 Marketwired. All rights reserved. All the news releases provided by Marketwired are copyrighted. Any forms of copying other than an individual user's personal reference without express written permission is prohibited. Further distribution of these materials is strictly forbidden, including but not limited to, posting, emailing, faxing, archiving in a public database, redistributing via a computer network or in a printed form.

Latest Stories
DevOps theory promotes a culture of continuous improvement built on collaboration, empowerment, systems thinking, and feedback loops. But how do you collaborate effectively across the traditional silos? How can you make decisions without system-wide visibility? How can you see the whole system when it is spread across teams and locations? How do you close feedback loops across teams and activities delivering complex multi-tier, cloud, container, serverless, and/or API-based services?
Today every business relies on software to drive the innovation necessary for a competitive edge in the Application Economy. This is why collaboration between development and operations, or DevOps, has become IT’s number one priority. Whether you are in Dev or Ops, understanding how to implement a DevOps strategy can deliver faster development cycles, improved software quality, reduced deployment times and overall better experiences for your customers.
In the 21st century, security on the Internet has become one of the most important issues. We hear more and more about cyber-attacks on the websites of large corporations, banks and even small businesses. When online we’re concerned not only for our own safety but also our privacy. We have to know that hackers usually start their preparation by investigating the private information of admins – the habits, interests, visited websites and so on. On the other hand, our own security is in danger bec...
The Internet of Things (IoT), in all its myriad manifestations, has great potential. Much of that potential comes from the evolving data management and analytic (DMA) technologies and processes that allow us to gain insight from all of the IoT data that can be generated and gathered. This potential may never be met as those data sets are tied to specific industry verticals and single markets, with no clear way to use IoT data and sensor analytics to fulfill the hype being given the IoT today.
Enterprises have been using both Big Data and virtualization for years. Until recently, however, most enterprises have not combined the two. Big Data's demands for higher levels of performance, the ability to control quality-of-service (QoS), and the ability to adhere to SLAs have kept it on bare metal, apart from the modern data center cloud. With recent technology innovations, we've seen the advantages of bare metal erode to such a degree that the enhanced flexibility and reduced costs that cl...
Without lifecycle traceability and visibility across the tool chain, stakeholders from Planning-to-Ops have limited insight and answers to who, what, when, why and how across the DevOps lifecycle. This impacts the ability to deliver high quality software at the needed velocity to drive positive business outcomes. In his session at @DevOpsSummit 19th Cloud Expo, Eric Robertson, General Manager at CollabNet, will show how customers are able to achieve a level of transparency that enables everyon...
Donna Yasay, President of HomeGrid Forum, today discussed with a panel of technology peers how certification programs are at the forefront of interoperability, and the answer for vendors looking to keep up with today's growing industry for smart home innovation. "To ensure multi-vendor interoperability, accredited industry certification programs should be used for every product to provide credibility and quality assurance for retail and carrier based customers looking to add ever increasing num...
“Media Sponsor” of SYS-CON's 19th International Cloud Expo, which will take place on November 1–3, 2016, at the Santa Clara Convention Center in Santa Clara, CA. CloudBerry Backup is a leading cross-platform cloud backup and disaster recovery solution integrated with major public cloud services, such as Amazon Web Services, Microsoft Azure and Google Cloud Platform.
In the next forty months – just over three years – businesses will undergo extraordinary changes. The exponential growth of digitization and machine learning will see a step function change in how businesses create value, satisfy customers, and outperform their competition. In the next forty months companies will take the actions that will see them get to the next level of the game called Capitalism. Or they won’t – game over. The winners of today and tomorrow think differently, follow different...
In his general session at 19th Cloud Expo, Manish Dixit, VP of Product and Engineering at Dice, will discuss how Dice leverages data insights and tools to help both tech professionals and recruiters better understand how skills relate to each other and which skills are in high demand using interactive visualizations and salary indicator tools to maximize earning potential. Manish Dixit is VP of Product and Engineering at Dice. As the leader of the Product, Engineering and Data Sciences team a...
@DevOpsSummit has been named the ‘Top DevOps Influencer' by iTrend. iTrend processes millions of conversations, tweets, interactions, news articles, press releases, blog posts - and extract meaning form them and analyzes mobile and desktop software platforms used to communicate, various metadata (such as geo location), and automation tools. In overall placement, @DevOpsSummit ranked as the number one ‘DevOps Influencer' followed by @CloudExpo at third, and @MicroservicesE at 24th.
The security needs of IoT environments require a strong, proven approach to maintain security, trust and privacy in their ecosystem. Assurance and protection of device identity, secure data encryption and authentication are the key security challenges organizations are trying to address when integrating IoT devices. This holds true for IoT applications in a wide range of industries, for example, healthcare, consumer devices, and manufacturing. In his session at @ThingsExpo, Lancen LaChance, vic...
Regulatory requirements exist to promote the controlled sharing of information, while protecting the privacy and/or security of the information. Regulations for each type of information have their own set of rules, policies, and guidelines. Cloud Service Providers (CSP) are faced with increasing demand for services at decreasing prices. Demonstrating and maintaining compliance with regulations is a nontrivial task and doing so against numerous sets of regulatory requirements can be daunting task...
What are the successful IoT innovations from emerging markets? What are the unique challenges and opportunities from these markets? How did the constraints in connectivity among others lead to groundbreaking insights? In her session at @ThingsExpo, Carmen Feliciano, a Principal at AMDG, will answer all these questions and share how you can apply IoT best practices and frameworks from the emerging markets to your own business.
Between the mockups and specs produced by analysts, and resulting applications built by developers, there exists a gulf where projects fail, costs spiral, and applications disappoint. Methodologies like Agile attempt to address this with intensified communication, with partial success but many limitations. In his session at @DevOpsSummit at 19th Cloud Expo, Charles Kendrick, CTO at Isomorphic Software, will present a revolutionary model enabled by new technologies. Learn how business and deve...