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Hi We are Hays International a specialist recruitment consultancy and have been retained by ORPIC to identify Shift Team Leader (SRIP) as advertised on the web. The current position is staff/direct hire posts with Orpic. Kindly Note the Position is Directly with Owner Company Project details – (https://www.orpic.om/pages.aspx?id=30) Location – Sohar , Oman Permanent Position Salary Range: USD 7000-9000 per month + Benefits Including Below Yearly Bonus Family Status Family Health Coverage Family Air Tickets Education assistance in Oman for kids if needed For Review I have attached the following, Kindly revert me with your Interest by updating your CV & PD form. I shall contact you with response to your application (Kindly mention available time n mob number to contact with your application) Ø Kindly update Recruitment checklist as requested by client Ø JD for Shift Team Leader (SRIP) Ø Also send me your original updated CV mentioning projects in detail Appreciate your kind response asap Cheers Githin Cleetus Recruiting experts in Oil & Gas HAYS Recruiting experts worldwide Block 19, 1st Floor, Office F-02 Knowledge Village, Dubai United Arab Emirates D: +971 (0) 4 364 4952 M: +971 (0) 52 703 4240 T: +971 (0) 4 361 2882 SHIFT TEAM LEADER, REFINERY & PETROCHEMICAL EXPERT SOHAR, OMAN
COMPANY INFORMATION
ORPIC is Created from the integration of three companies - Oman Refineries and Petrochemicals Company LLC (ORPC), Aromatics Oman LLC (AOL) and Oman Polypropylene (OPP) - Orpic is one of Oman`s largest companies and is one of the rapidly growing businesses in the Middle East`s oil industry.
JOB DESCRIPTION
Senior Operations Engineer is responsible for using technical and plant knowledge to support the process area and shift team in achieving safe, profitable, reliable, and environmentally responsible production. To be successful, an Operations Engineer must fulfil several roles and responsibilities
JOB REQUIREMENTS
Diploma preferably in Chemical Engineering for Shift Staff Minimum of 7 years' experience in plant operation including training, of which at least 3 years should be in an applied position. Experience in Crude & Vacuum Distillation /Hydrocracker integrated with Diesel Hydrotreater/Delayed Coker and Bitumen Blowing Process Units Uses and reinforces the use of established policies and procedures, as well as operating knowledge, to ensure activities are performed in a safe and an environmentally correct manner. Works safely and promotes safe work practices of others within their respective work areas to ensure a safe work environment. Gives and receives clear, concise, and relevant instructions and information using appropriate verbal, written, and radio communication Provides coaching, mentoring and counselling as necessary to improve employee performance, resolve conflicts, and to adequately staff the area to achieve safe production. Manages the day-to-day operation of the process to achieve profitable production whilst adhering to all applicable HSE policies and procedures Maintains, reinforces, and extends job skills through training and application of training. Shares knowledge and experience to support shift team goals
JOB BENEFITS
An all inclusive monthly and tax free benefits package will be offered which includes; Family Status for Expats 30 Working days Annual Leave Accommodation Transportation Medical Insurance
SALARY DESCRIPTION
Highly competitive tax-free remuneration package
CANDIDATE INFORMATION
Are you a Permanent Staff Employee or a Contract Employee?
Staff/Permanent Employee Contract/Temporary Employee
If Contract/Temporary Employee, please specify the duration and if contract is renewable.
COMPENSATION
1. Is your compensation split across several countries? (Yes or No) If YES, please detail the countries and split percentage
2. In which country (or countries) are you being paid by your current employer?
3. In which country or countries do you pay personal income tax?
4. In which country's social security system do you participate?
5. What is your gross annual base salary and net annual base salary (after taxes and social security deductions)? (Please detail both amounts, currency and frequency eg. paid monthly, 13 times etc.)
6. What short term incentives do you have? ( ) Bonus Plan ( ) Others (please specify) ( ) None
Please detail frequency and value, the basis for the award (company and/or personal performance), and the amount your received in each of the last two years.
7. What long term incentives do you have? ( ) Stock grants (company gives you stock) ( ) Stock options (call option on the stock of the company) ( ) Stock purchase plan (buy stock at a discounted price through payroll deductions) ( ) Other ( ) None of these
Please detail each element, including value, vesting period and other conditions
8. How many days paid vacation do you have?
9. What allowances or benefits do you receive? ( ) Car provided by company ( ) Car personal leasing support/car allowance ( ) Car with driver provided ( ) Fuel card: international/national ( ) Representation allowance ( ) Foreign service/Hardship allowance ( ) Housing allowance ( ) Household utilities (electricity, water, etc.) ( ) Personal education/language school ( ) Schooling for dependents ( ) Paid home leave ( ) Daily expenses ( ) Health care cover ( ) Paid home leave: during vacations only/any time ( ) Health care cover ( ) Accident cover ( ) Pension (please detail type and contributions e.g. defined benefit/defined contribution) ( ) Other (please detail below) ( ) None of these
Please detail frequency, value, whether gross or net and any other special conditions.
10. Please provide details of your expected Salary (Base, Net or Gross)
11. How flexible is your current work environment? o Full time office based o Part-time home office o Home office full time
Please detail (how many working days/hours per week, off days per week, timings, etc...)
11. Do you have any restrictions on future employment such as a non-competition clause? Please detail
12. What is your notice period?
13. If you will be selected, will you be working as a
Single Status Family Status
If Family Status, please provide details of the persons who will accompany you (Relationship, Gender, Age)
14. Please provide 2 Professional References
15. Information gathered is OK to be released to Hays Oil & Gas Client?
Yes
No
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By Jeff Gunderson
Oil and gas production is a colossal, fast-evolving, and wide-ranging industry that is shaped by significant market drivers, is vital to the global economy, and represents the world's largest industry in terms of capital value. Like the industry itself, water and wastewater treatment in oil and gas is broad and complex, with numerous issues, and spanning several areas -- from the upstream and downstream segments to conventional oil and gas to the unconventional plays including shale gas and liquids, coalbed methane, tight gas, and heavy oil, among others.
Oil and gas is not just one market, it's many markets, and some have water and wastewater treatment challenges that are highly specific and require unique and increasingly innovative solutions, observed Jonathan Rhone, president and CEO of Vancouver, B.C.-based Axine Water Technologies.
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| A mud pit in North Dakota's Bakken Formation. Photo by Joshua Doubek. |
Many of the treatment issues in oil and gas are also based on the regional geology, much like the mining industry, said Rosemary Niechcial, director of infrastructure – mining, oil & gas with Black & Veatch. "For example, there are treatment challenges specific to the Alberta oil sands or the Bakken Shale Formation that aren't found anywhere else in the world," she said.
In recent years, the industry as a whole has begun to experience a significant change as increasingly more attention moves towards unconventional sources. In An Overview of Unconventional Oil and Natural Gas: Resources and Federal Actions, a report prepared by the Congressional Research Service, advances in hydraulic fracturing, directional well drilling, and reservoir stimulation has enabled oil and gas production from tight, impermeable unconventional formations that were previously uneconomical to produce, changing the U.S. energy posture and global energy markets.
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| Fracking operations in progress in the Bakken Formation. Photo by Joshua Doubek. |
This global shift to unconventional sources represents a huge driver for the treatment industry and an enormous opportunity for new technologies, according to Rhone. "Many of the extraction techniques associated with these newer plays -- such as steam-assisted gravity drainage and water flood -- are very water- intensive and generate high volumes of wastewater, which can be very complicated," he said. "Plus, as many of the old oil fields reach the end of their productive lives, these methods are now also being used on conventional sources to drive out the last remaining hydrocarbons."
As in other industries, water recycling is taking on increasing significance in the oil and gas industry, especially as water resources become scarcer.
"Raw water costs are also rising significantly, generating higher interest in adopting advanced technologies so that wastewater can be treated and recycled back in operations, reducing freshwater intake requirements," Rhone said.
Manish Backliwal, international business development manager with Aquatech, said due to stringent environmental regulations, oil companies are looking at economical and innovative ways to recycle more produced water as opposed to discharging it.
Backliwal, who specializes in upstream oil and gas, said companies are striving to recycle as much as 95 to 98 percent of produced water coming from enhanced oil recovery operations. "More and more, innovation in water recycling is being focused on addressing that last 2 to 5 percent and how to economically treat those highly-concentrated impurities," Backliwal said.
In addition to driving more water recycling, water scarcity is also pushing more oil and gas producers to find alternative, lower-quality sources of water that can be utilized for meeting process water needs. Doing so, however, can present a new set of treatment challenges.
"Brackish water is increasingly coming into the picture, but this type of water also has greater levels of total dissolved solids," Backliwal said. "The chemistry of the produced water can be very complex, with high concentrations of organics, silica or other elements creating distinct treatment challenges."
As higher quality sources become more difficult to access, oil and gas companies are also turning more to wastewater treatment plant effluent, according to Black & Veatch's Niechcial. "We are seeing more of this across the board, wherever an operation is in close proximity to a municipality, such as in Mexico," she said.
"But in many cases, the newer unconventional plays are not located within easy distance to municipalities," she added. "Then, the trend is to utilize poorer-quality, non-potable water, and this is where the treatment challenges really come in because a lot of these sources are highly saline."
Many long-standing and new drivers in the oil and gas industry, propelled by macro demands, are continuously pushing the market in terms of the development of new treatment technologies and innovations. In addition to solutions that help solve problems such as meeting higher water quality discharge requirements, end users increasingly need solutions that are more adaptive, robust and that are capable of treating more problematic sourced water. At the same time, oil and gas companies are also pressing for technologies that offer greater treatment performance at lower costs.
Becky Tomasek, upstream market sector leader for CH2M HILL's water market, said as the upstream industry moves towards more brackish water use, companies are relying more and more on chemical addition and mechanical filtration for removing iron and other metals that can cause scaling. "For hydraulic fracturing, many operators want to develop a clean brine from either brackish water sources or recycled produced water, and so in some cases they are focusing on removing suspended solids and hardness," Tomasek said. "If the produced water isn't needed, then flash evaporation can be used, leaving only the solids to be discharged."
In terms of treatment innovations, Tomasek sees advancements both in membranes and in distillation. "A lot of the new water sources have total dissolved solids levels that are higher than what a typical membrane can handle. So we are seeing more robust, ceramic-type membranes that can withstand the fouling that may occur," she said. "With distillation, technologies are being introduced that can vaporize and condense salt water in a very efficient fashion"
Devesh Mittal, vice president and general manager of Aquatech's shale gas division, said fluctuating oil and gas prices are prompting drillers to move operations more frequently, which in turn is forcing treatment specialists to be more adaptive. "Oil and gas is a constantly-changing industry. Drillers will change plans quickly and move to another formation if the economics of drilling are more favorable," he said.
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| Aquatech's SmartMOD is a modular evaporator that is flexible, redeployable and specifically engineered for the harsh environment of the Alberta oil sands. |
For example, more drillers right now are shifting to the oil- or liquid-bearing regions because oil prices are collectively higher than the price of gas, Mittal noted. "When these shifts occur, we need to be able to respond quickly, have the right assets in the correct locations, and be prepared to handle new water characteristics and different water balance dynamics," he said.
For meeting challenges associated with changing treatment needs, Aquatech provides solutions that are flexible, adaptive and that offer service in multiple formats, according to Mittal. "We are also focusing on making systems simpler and developing combined solutions that are capable of serving the broader oil and gas market," he said.
Indeed, in many instances, solutions to problems may not necessarily require new technologies but rather an integration of existing technologies, said Samir Davé, downstream market sector leader for CH2M HILL's water market. "What matters are the technologies chosen, how they are integrated and in what sequence they are used," Davé said. "The treatment strategies should also vary based on the dynamics of the formation. For example, the water characteristics in the Eagle Ford Formation could be very different compared to the Marcellus Shale, requiring different approaches."
An integrated approach is also critical in addressing challenges on the downstream side of the industry, Davé said. "We are seeing lots of interest from clients who need help meeting very stringent limits related to nitrogen, phosphorus, metals like copper and selenium, and also with regard to effluent temperature," he said. "With regulations requiring selenium to be removed to parts per billion level, an integration of technologies is needed."
Another area of focused innovation and development is in the design of modular treatment systems that are compact, easily-transported and can be installed very quickly.
"These types of units are inspired by the off-shore industry where space is at a premium and can be very effective in places where labor costs are high, such as Alberta and Australia," said Aquatech's Backliwal. "Since modular treatment systems are already essentially built, the onsite installations are mainly limited to assembly, which can be much more cost-effective."
Aquatech has developed a modular evaporator specifically for the oil sands market that is flexible, redeployable and engineered to withstand the extreme climate of northern Alberta. Called the SmartMOD, the technology is capable of significantly reducing field installation labor and costs.
About the Author: Jeff Gunderson is a correspondent for Industrial WaterWorld. He is a professional writer with over 10 years of experience, specializing in areas connected to water, environment and building, including wastewater, stormwater, infrastructure, natural resources, and sustainable design. He holds a master's degree in environmental science and engineering from the Colorado School of Mines and a bachelor's degree in general science from the University of Oregon.
ICM have the following open vacancies on Cyber & Conventional Jackup rigs (Long term) to be filled urgently:
· OIM (Drilling background) x2
· Barge Master x2
· Tool Pusher x4
· Driller x4
· Assistant Driller x4
· Derrick man x4
· Pump man x4
· Floorman x12
· Maintenance Supervisor x2
· Chief Mechanic x2
· Mechanics x4
· Chief Electrician x2
· Electricians x4
· Electronic technician x2
Also looking for:
· Toolpusher – cyber jackup- Rusia (European only)
· QHSE Manager (French/ English) residential position (Nebosh & Drilling experience is a requirement) – West Africa
· Advance Drilling Instructor (residential / rotational) Europe
To apply send your CV in Word Format, State Nationality, Date of Birth, Availability & expected dayrate in USD.
Please follow us on LinkedIn : http://www.linkedin.com/company/3105337?trk=tyah for exciting more updates
Looking forward to your application
Best Regards,
HR Manager
International Consulting Management
Pre-recording of information.Proper secondary well control follows a planned course of action. Pre-recording relevant information avoids unnecessary delay. The following aspects concerning the pre-recording of information are discussed:
A Kick Control Worksheet is available (CLICK LINK).
During drilling operations, the Worksheet must be updated regularly to correct depth-dependent data and additionally, whenever significant changes occur in parameters such as casing and hole sizes, mud gradient, drillstring configuration, nozzle sizes, formation characteristics, etc.
Kick control worksheets should be available at all times that BOPs are installed and in use.
For development they should be updated before entering the potential oil reservoirs. For exploration or appraisal wells, they should be updated at least daily or every 200 m, whichever is the sooner.
Well control operations are performed at reduced pump speeds in order to:
·allow weighting up and degassing of the mud;
·reduce loads on surface equipment;
·increase reaction time for correct choke adjustments.
Operation of the pump at a pressure too close to the setting of its relief valve is dangerous. If the relief valve opens, mud will flow back through the drillpipe and standpipe manifold.
Circulation pressures at the reduced pump speeds must be known. Before starting to drill with a new bit and at the beginning of each shift, the driller shall observe pump pressures at selected circulation rates and record the results in the daily drilling report and kick control worksheet.
Circulation pressures may differ considerably when using a different equipment hook-up (e.g. circulating head/chicksans vs kelly or top drive).
Slow circulation rates should be taken with the equipment hook-up which is planned, or most likely to be used during the well killing operation.
Slow circulation rates and pressures can be plotted as a straight line on a graph using log log paper. Appropriate pump pressures for any pump rate can be found using this graph, provided the mud properties and drillstring configuration do not change.
Friction losses in subsea BOP stack kill-and choke lines represent a significant proportion of the back pressure developed in the annulus and, if not taken into account, could lead to a fracture of the formation around the casing shoe.
The friction losses in kill-and choke lines (both separate and combined) should be determined at various rates after landing and testing the BOP stack, but before drilling out the cement in the casing.
The pressure losses can be established by comparing pump pressures obtained whilst circulating:
·Down the drillpipe and up the marine riser.
·Down the drillpipe and up the kill-and choke lines separately and combined.
Alternatively, the value of the friction losses can be measured directly, and perhaps more accurately, by pumping down the lines, separately then combined, with returns up the marine riser.
In deep water operations, suitably low circulation rates should be selected.
Choke and/or kill line pressure losses for a particular subsea BOP stack set-up and waterdepth will only change when different mud properties are used.
The weighting up capacity depends on the maximum rate at which barytes can be added over prolonged periods. It is recommended that this rate is established for mud gradients in normal use.
An important advantage of the balanced mud method is that a well can be controlled in one circulation. This is done by employing a constant pump speed whilst circulating a mud which has been weighted up.
If mud mixing facilities cannot achieve the required increase in mud gradient, it will not be possible to control the well in one circulation.
Several circulations may be required, the gradient being raised in stages during each circulation, or on a gradual continuous basis while pumping.
One option to obtain the required mud weight quickly is to prepare kill mud prior to drilling ahead in possible overpressured formations. This practice will facilitate speedy well killing operations.
Preparing kill mud in advance is recommended for wells in which increased mud weights are expected to be used. The recommended kill mud gradient depends on the expected formation pressures to be encoutered, but as a general rule may be 10-20% higher than the actual mud weight in use. The correct mud weight can be obtained quickly by diluting the kill mud with the original mud.
There is a close relationship between the above parameters and the ability to safely handle a kick without causing formation failure in the open-hole section. Given certain fixed (or assumed) values of these parameters, combined with an acceptable kick tolerance for the rig drilling the well, a minimum required formation strength at the shoe may be specified.
The ability to safely handle a kick without causing formation failure in the open hole section needs to be reviewed as soon as the actual formation strength at the shoe is known and whenever any of the other parameters change.
Section 6.13 contains equations which show how the minimum required formation strength is calculated for specific influx volumes.
Influx volumes of 5-15 m3 (30-90 bbl) may be used as the maximum allowable kick tolerance. This depends on the following:
Likely influx volumes for the drilling and reservoir conditions prevailing can be calculated/determined from equations given in the Casing design guide However, results largely depend on realistic values of kick detection threshold volumes for the rig used to drill the well. Experience has indicated that well-trained crews can perform BOP drills in three to four minutes. BOP drills shall be carried out to achieve and maintain this performance standard.
Periodic checks shall be made to establish the magnitude of the influx which can still be safely handled with the mud currently in the hole (kick tolerance), i.e. without causing formation failure. These checks will indicate the extent to which the density can be increased to control formation pressure or whether casing should be set prior to drilling deeper. New calculations shall be made whenever any of the parameters have, or will be changed.
In drilling operations the borehole fluid pressure must not exceed the formation strength at any point in the open hole. During well control operations the maximum allowable borehole fluid pressure at the casing shoe is normally considered to be the critical factor, based on the assumption that the weakest formation is at the shoe. For practical purposes, this pressure is referred to at the surface as the Maximum Allowable Annular Surface Pressure (MAASP).
The MAASP equals the "formation strength" at the casing shoe minus the hydrostatic head of the mud and/or influx in the casing. The "formation strength" is generally established by making a leak-off test during the course of the drilling operation.
In principle, MAASP should not be exceeded during well control operations, as long as the top influx has not yet reached the shoe, because of the danger of breaking the formation which may result in a (internal) blowout. However, there are situations which may justify exceeding the leak-off value during well control operations when the detrimental effects of having larger influx volumes entering the borehole are considered worse than the risk of encountering losses. There are exceptional cases where it would be better to take the risk of breaking the formation and to have an internal blowout than to have a flow to surface. Exceeding MAASP before top influx is at the shoe will not always have such detrimental effects, because of hidden safety factors in MAASP which are explained as follows:
The decision to exceed MAASP and the extent to which it could be exceeded depends very much on the circumstances under which the kick is experienced.
Drilling staff should be sufficiently conversant with well control principles that they can recognise and handle such situations. Main criteria to be considered are:
Some control panels of remotely controlled chokes have an automatic MAASP control feature which keeps MAASP constant as soon as it is reached. When this feature is used in situations whereby MAASP should be exceeded, for instance when top influx is already inside the casing shoe, more influx is allowed to enter the hole unnecessarily which may lead to worsening situations. It is recommended not to use this feature, but to adjust the remotely controlled choke(s) manually from the control panel.
To calculate MAASP, three parameters should be known:
If any of these three parameters changes, the MAASP has to be re-calculated.
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