Tell me about yourself?
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This question is one of the most frequently asked questions. Where do you start? What do they really want to know? Are you to begin from elementary school or college? You have to be very careful on how you answer this question because your answer here sets the tone for the rest of the interview. This question is mostly asked as an icebreaker but if you did not prepare for it, it becomes a real problem.The right approach to this is to discuss your key strengths and how they relate to the job. Talk about a few of your accomplishments. Talk about your current employer and then tell them how you see yourself fitting into a position at their company.
Tell me about roles & responsibilities of Wellhead Operator?
Wellhead operators typically move from well to well and are responsible for optimizing production of the gas or oil wells that are on their "field run". Duties will vary based on the size of the field, whether it produces oil or gas (as well as natural gas liquids, or a mix), and the types of equipment required.
What are the main job duties of wellhead Operator ?
Wellhead Operator responsibilities are to operate engines and pumps to shut off wells according to production schedules, and to switch flow of oil into storage tanks; monitor control panels during pumping operations to ensure that materials are being pumped at the correct pressure, density, rate, and concentration; perform routine maintenance on vehicles and equipment; repair gas and oil meters and gauges; unload and assemble pipes and pumping equipment, using hand tools; attach pumps and hoses to wellheads; open valves to return compressed gas to bottoms of specified wells to repressurize them and force oil to surface; supervise oil pumpers and other workers engaged in producing oil from wells; start compressor engines and divert oil from storage tanks into compressor units and auxiliary equipment to recover natural gas from oil; prepare trucks and equipment necessary for the type of pumping service required; drive trucks to transport high-pressure pumping equipment, and chemicals, fluids, or gases to be pumped into wells; mix acids, chemicals, or dry cement as required for a specific job; control pumping and blending equipment to acidize, cement, or fracture gas or oil wells and permeable rock formations.
What does a well Operator do?
The primary purpose of a wellhead is to provide the suspension point and pressure seals for the casing strings that run from the bottom of the hole sections to the surface pressure control equipment. While drilling the oil well, surface pressure control is provided by a blowout preventer (BOP).
What are the skills required for wellhead Operator employee in order to success in his work?
Watching gauges, dials, or other indicators to make sure a machine is working properly, Controlling operations of equipment or systems, Using logic and reasoning to identify the strengths and weaknesses of alternative solutions, conclusions or approaches to problems, Monitoring/Assessing performance of yourself, other individuals, or organizations to make improvements or take corrective action, Repairing machines or systems using the needed tools.
Describe the abilities you have in order to work with us as wellhead Operator?
I have the ability to tell when something is wrong or is likely to go wrong. It does not involve solving the problem, only recognizing there is a problem, quickly and repeatedly adjust the controls of a machine or a vehicle to exact positions, coordinate two or more limbs (for example, two arms, two legs, or one leg and one arm) while sitting, standing, or lying down. It does not involve performing the activities while the whole body is in motion, see details at close range (within a few feet of the observer), quickly respond (with the hand, finger, or foot) to a signal (sound, light, picture) when it appears.
What are the knowledge elements you obtained from your education, training and work experience would support your wellhead Operator career?
The Knowledge of machines and tools, including their designs, uses, repair, and maintenance, arithmetic, algebra, geometry, calculus, statistics, and their applications, raw materials, production processes, quality control, costs, and other techniques for maximizing the effective manufacture and distribution of goods, relevant equipment, policies, procedures, and strategies to promote effective local, state, or national security operations for the protection of people, data, property, and institutions, the structure and content of the English language including the meaning and spelling of words, rules of composition, and grammar.
How would you describe (needed wellhead operator or your) work style?
My work style matching exactlty what cashier job requires by: being reliable, responsible, and dependable, and fulfilling obligations, developing one's own ways of doing things, guiding oneself with little or no supervision, and depending on oneself to get things done, being honest and ethical, being careful about detail and thorough in completing work tasks, being open to change (positive or negative) and to considerable variety in the workplace.
What is wellhead maintenance?
Valve and Wellhead Maintenance. ... Our highly competent wellhead maintenance engineers, many with direct experience from OEM's, will maintain, service and repair all valves, actuators and wellhead equipment originally supplied by the OEM's.
What is wellhead natural gas?
Natural Gas – From Wellhead to Burner Tip. The process of getting natural gas out of the ground, and to its final destination to be used, is a complicated one. ... The Extraction section focuses on the drilling process, and how natural gas is brought from its underground reservoirs to the surface.
What is the wellhead price?
Definition of wellhead price. : the price less transportation costs charged by the producer for petroleum or natural gas.
What is a wellhead in oil and gas?
A wellhead is the component at the surface of an oil or gas well that provides the structural and pressure-containing interface for the drilling and production equipment.
What is a wellhead connector?
Cameron wellhead connectors are fast-makeup connectors used as end connections for wellhead spools, housings, and BOPs. They are built for reliability and designed for a wide range of bore sizes and working pressures. Options are available for eliminating weld-on or threaded wellhead connection procedures.
Why are you interested in the role?"
As a job seeker, the best way to answer this common interview question is to emphasize the merits and exciting aspects of the position itself to convey your enthusiasm, rather than a time to rehash how your background and work experience is a fit. Think of it this way: Even if you’re the perfect fit, that’s what the rest of the interview is to demonstrate. This is the time when you get to demonstrate your enthusiasm about the work you’re about to do. Actually wanting to do a certain job counts for a lot.
What do you know about this organization?
This is a similar question to the previous one, but you still might get both in one interview. Essentially, the interviewer wants to know whether you care enough about this position and the business to take the time to do your homework. So do your homework! While this isn't a test, you should be aware of the business's major initiatives, mission, and qualities. You should also look into all aspects of the business that are related to the position or function you'll be performing. For example, if you're interviewing for a marketing role, make sure to look at all of the company's social media accounts.
What's one of your greatest professional achievements?
Hearing about what you've accomplished is a great way for a hiring manager to see how you might contribute to the company. Make sure you describe the situation thoroughly but without getting too bogged down in details that aren't relevant or won't interest the interviewer—after all, you
Tell me about a time when you disagreed with a coworker. How did you handle it?
Be ready to have anecdotes about your experiences for these kinds of situational interview questions. They don’t have to be about the most interesting days you’ve had at work; instead, think of situations that have highlighted the fact that you’re mature and capable of working with a variety of people, even if you don’t always see eye-to-eye.
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Do you prefer working independently or on a team?
This is a common question when a hiring manager wants to assess whether you will be a good fit, culturally. Be as honest as possible when you respond to this, but make sure it’s clear you’re comfortable working collaboratively and on your own. Companies want to hire people who are fun and easy to work with — but also those who can manage whatever they need to on their own.
How do you deal with pressure or stress?
The short answer you want to give is: “Well.” While you probably don't want to literally say that, the idea is to convey competence to deal with difficulty and hopefully pressure is not a problem for you. Frankly, this question tends to come with high-pressure, stressful jobs or companies and they want to know whether you’ll be able to handle tough situations. Hopefully, you have self-selected into this kind of job and applied to the company and role with your eyes open about those realities and believe you can thrive in an environment that demands a lot of you.
When you're working on multiple projects, how do you keep yourself organized and on track?
Employers want to know that you stay on top of things. Be ready to explain how you manage your current responsibilities -- whether in a detailed calendar or to-do list or through some kind of organizational service or app.
What are you expecting in terms of salary?
We believe that anchoring your salary expectations to your prior salary is the surest way to get very incremental pay raises. Ideally, you’ve done your compensation research and understand the salary possibilities for the role. If not, and you must anchor your salary expectations to what you have previously earned, don’t frame the expectations that way. Simply state the number you believe you should receive for the role (and make sure it’s more than what you would settle for, just in case it sets an anchor figure for future pay negotiation).
What is your dream role?
This precise title and position might not be your end game, but the interviewer wants to see that it at least matches up with your overall ambitions. For example, if you're interviewing for a programming job and your goal is to be a chef, that's bound to raise a few eyebrows.
What would your first 30, 60, or 90 days look like in this job?
This may seem like an unreasonable question, but if you think about it from the employer’s perspective, they are trying to hire someone to fill a gap or hole in their team. They have real, usually time-pressing needs and they want to see at least improvements in the issues they’re facing when they hire you.
Therefore, be prepared to talk about what you think you will accomplish in a 1–3-month horizon. Ideally, this is based on a clear understanding of what the job entails and what the company’s challenges are.
How would you improve this company/specific operation?
Your vision for improving the company is the reason why you—or someone else—will get hired. Come prepared with ideas for how you'd make one aspect of the company—something that is, of course, related to the job function of the position in question—better.You don't need to disparage the way the company is currently doing things to make your point; instead, just demonstrate that you've thought about this question and have innovative ideas.
BSEE regulations apply, as of their effective date(s), to all operations conducted under a lease. Operations conducted after the effective date of certain provisions of the final rule (April 30, ) may proceed on the basis of a previously-approved permit if those operations are conducted in accordance with both the approved permit and the applicable regulatory requirements in effect on the date the operations are conducted. BSEE does not require that an operator submit a new permit application in those circumstances simply because the new requirements have taken effect. However, if compliance with applicable regulatory requirements would require material modifications to your operations that would place them outside the terms of the approved permit, you would be required to submit a new or modified permit application that demonstrates that your operations will be completed in accordance with the newly effective regulatory requirements.
The preamble to the final rule states: “[I]f there are any indications of an inadequate cement job, the operator must evaluate the cement job as required in § 250.428.” 84 FR -. With respect to that evaluation, the preamble states: “If the operator encounters circumstances that the approved permits do not address (including PE certification), it would be required to submit a revised permit for BSEE approval that would include the PE certification.” 84 FR (”If an operator encounters circumstances that are not described in an approved permit, such as unplanned lost returns, then a new BSEE approval would be required at that time”). Section 250.428(c) identifies examples of “indication[s] of inadequate cement job,” including “no cement returns…to expected height.” Thus, if the cement job did not go as approved in the permit, including a discrepancy in TOC, then the job is inadequate and further action is required and may require a new PE certification.
Section 250.462(d) requires reevaluation of the operator’s source control and containment equipment if there is a well design change. As explained in the preamble, BSEE requires notification for any well design change, which must be submitted at the time the operator submits a revised permit. 81 FR . This may include, but is not limited to, changes to the pore pressures, fracture gradients, drilling fluid weights, and casing setting depths or casing materials. These parameters may affect the source control and containment capabilities for a particular well and the associated well containment screening tool (WCST).
A revised screening tool will need to be submitted in a revised permit if any of the following has changed for the primary or secondary strings analyzed in the WCST:
Each production packer setting depth will be evaluated on a case–by-case basis. Each well and situation is unique. It is reasonably possible that BSEE will approve a setting depth for a production packer that will allow for future potential work below the packer. The provisions at §§ 250.518(e)(3) and 250.619(e)(3) do not require that BSEE only approve a setting depth that would preclude future potential work below the packer.
The new regulations are not intended to hinder the installation of production equipment by setting a fixed interval length that must be met or to hinder an operator's flexibility to intervene in or manage its well as necessary. During the permit application process, BSEE may request additional information to justify your specified production packer setting depth to ensure that the packer is set as required in these sections to help ensure long-term equipment reliability.
The final rule preamble explained that “BSEE wants to ensure that the packer is not set too high, so that, if there is a problem with the packer in the well (e.g., a leak), operators will have enough space above the packer to pump a sufficient volume of weighted fluid into the well to exert a hydrostatic force greater than the force created by the reservoir pressure below the packer.” 81 Fed. Reg. , (April 29, ).
BSEE has outlined the minimum RTM and RTM plan requirements in the regulations. Since the Rule, the RTM planning requirements have been designed to be “flexible, performance-based measures that better reflect BSEE’s intention that operators use RTM as a tool to improve their own ability to prevent well control incidents while providing BSEE with sufficient access to RTM information to evaluate system improvements.” final rule preamble, 81 FR ; see also final rule preamble, 84 FR (“The WCR’s RTM requirements were themselves largely performance-based, relying primarily on the operator’s development of an RTM plan tailored to its operations but built off of core principles. The revisions implemented here do not reflect a sea change in philosophy…”). With respect to enforcement, the final rule preamble states: “This regulation requires that operators develop and implement RTM plans, and specifically requires that those plans be made available to BSEE upon request. If BSEE has any concerns with an operator’s RTM operations, then BSEE may undertake inspections and enforcement actions to ensure compliance with the regulations. BSEE has additional options such as routine onsite inspections or verifications through the permitting process to ensure that RTM plans are implemented in compliance with the regulations.” 84 FR . The regulations since have required that operators both “develop and implement” RTM plans. 30 CFR 250.724(c) (emphasis added). These principles are unchanged in this rulemaking.
As a general principle, BSEE considers the term “significant and/or prolonged” loss of RTM capability as a period of time “that potentially could increase the risk of a well-control event.” final rule preamble, 81 FR . “BSEE did not intend that proposed requirement to apply to minor or routine interruptions in RTM capabilities that pose no significant risk to safety or of a LWC.” final rule preamble, 81 FR . This regulation is not prescriptive and thus does not establish an express time period. An operator should use its ordinary prudence and industry expertise to establish in its RTM plan which losses of RTM capability should be characterized as “significant and/or prolonged,” taking into account the prior BSEE descriptions. Although it is generally the operator’s responsibility to initially define in its plan which losses of RTM capability will be considered “significant and/or prolonged” based on the facts associated with the RTM system’s interruption, BSEE would typically expect that a reasonably prudent operator would take action under its plan pursuant to 250.724(c)(6) if that operator loses any real-time monitoring capabilities for a 24 hour period.
The rig personnel should not be considered “monitoring personnel” for purposes of the RTM planning requirements at 250.724(c)(5) and (6) furthermore, rig personnel and RTM personnel should be in separate locations for a given well. The final rule preamble clarifies: “BSEE requires the rig personnel and monitoring personnel to be separate individuals.” 84 FR . The operator is not precluded from having personnel on the rig performing real-time monitoring functions, but those individuals may not serve as the “monitoring personnel” required by regulation. BSEE requires the operator to identify in the RTM plan how the RTM data will be transmitted and monitored, requires the rig personnel and monitoring personnel to be separate individuals, and requires certain communication capabilities among personnel, but does not prescriptively dictate the establishment of an onshore monitoring center, or even require that monitoring personnel must be onshore. See, e.g., 84 FR . As noted in the preamble, “[w]ith currently available technology, operators are capable of using RTM remotely on computers and tablets using web based applications. This allows for subject matter experts to utilize the data anywhere and at any time as necessary, as detailed in the company’s RTM plan.” Id.
BSEE regulations apply, as of their effective date(s), to all operations conducted under a lease. Operations conducted after the effective date of this regulation (April 30, ) may proceed on the basis of a previously-approved permit if those operations are conducted in accordance with both the approved permit and the applicable regulatory requirements in effect on the date the operations are conducted. BSEE does not require that an operator submit a new permit application in those circumstances simply because the new requirements have taken effect. However, if compliance with applicable regulatory requirements would require material modifications to your operations that would place them outside the terms of the approved permit, you would be required to submit a new or modified permit application that demonstrates that your operations will be completed in accordance with the newly effective regulatory requirements
BSEE is currently working with the industry to ensure that the terminology, data, and content for failure reporting information is consistent with the existing data reporting systems that are currently being used within a large part of the industry. We believe that consistent reporting processes and formats will facilitate other sharing of data across the industry. BSEE will also be providing operators with the option of reporting information directly to the SAFEOCS reporting system through the Bureau of Transportation Statistics (BTS). BTS is currently ensuring that the systems and processes are in place to accept this type of data directly from operators. BSEE will be issuing specific guidance on these issues in the next several weeks. Until this process is fully operational, operators should use one of the following options to report failures:
Download the BOP Component Failure Form from the SafeOCS website (www.safeocs.gov) and submit it electronically directly to BSEE at . The form will be available on July 28, .
Print the BOP Component Failure Form out and submit a paper copy directly to BSEE: Chief, Office of Offshore Regulatory Programs Bureau Safety and Environmental Enforcement Woodland Road Sterling, VA
Send a faxed hard copy to Chief, Office of Offshore Regulatory Programs at 703-787-.
BSEE will protect all confidential and proprietary information included in these submissions in accordance with governing law
Section 250.731 requires that you submit updated information in your next submittal if a rig has moved off location from the well (due to a storm or for any other reason). For example, the information listed in § 250.731 must be updated (or confirmed still to be accurate) and submitted with an APD, APM, or other necessary submittal when the rig moves back onto the well. Also, if a rig has moved off location (due to a storm or for any other reason), you must follow the rig movement reporting requirements according to § 250.712. If operations are suspended to make repairs or changes to any part of the subsea BOP system, you must also follow the requirements of § 250.734(b).
The rule refers to “the maximum environmental and operational conditions anticipated to occur at the well.” The regulations do not address the “most extreme load case.” For purposes of identifying maximum anticipated pressures, the definitions of MASP and MAWHP set forth in API Standard 53 are sufficient. However, the Independent third party must also take into account the specific environmental and operational conditions at the well (e.g., temperature and H2S). As BSEE explained in the final rule preamble, in order to assess these well conditions, operators should rely on “reasonably predictable, site-specific conditions instead of hypothetical worst-case conditions.” 81 Fed. Reg. (April 29, ). MASP for surface BOPs and MAWHP for subsea BOPs would ordinarily reflect reasonably predictable, site-specific conditions on which a certification pursuant to section 250.732(c)(2) may be based.
30 CFR 250.734(a)(1) requires use of dual shear rams on subsea BOPs no later than April 29, . 30 CFR 250.733(b)(1) requires that surface BOPs on new floating production facilities installed after April 29, , comply with the regulatory requirements in § 250.734(a)(1), including the requirement to use dual shear rams.
The final rule establishes numerous equipment and process requirements that are ancillary to the operation of dual shear rams as well as to other types of rams and other components of subsea BOPs. For example, § 250.734(a)(3)(i) requires that each subsea BOP have sufficient subsea accumulator capacity to close each required shear ram, one pipe ram, and ram locks, and to disconnect the LMRP. BSEE intended such ancillary requirements to take effect at the same time as the requirements for installation or availability of the specific equipment or component that the ancillary equipment or process is designed to operate. So, for example, the accumulator capacity closure requirement of § 250.734(a)(3)(i) must be met by April 29, .
The following provisions of the final rule also fall under the dual shear rams requirements; therefore, with regard to operating the dual shear rams, you must comply with these requirements by the April 29, , compliance date:
BSEE regulations apply, as of their effective date(s), to all operations conducted under a lease. Operations conducted after the effective date of this regulation (April 30, ) may proceed on the basis of a previously-approved permit if those operations are conducted in accordance with both the approved permit and the applicable regulatory requirements in effect on the date the operations are conducted. BSEE does not require that an operator submit a new permit application in those circumstances simply because the new requirements have taken effect. However, if compliance with applicable regulatory requirements would require material modifications to your operations that would place them outside the terms of the approved permit, you would be required to submit a new or modified permit application that demonstrates that your operations will be completed in accordance with the newly effective regulatory requirements.
As described in the preamble to the final rule, “[this provision] is intended to give District Managers the necessary flexibility and discretion to require [BOP system tests] as needed in specific cases to fulfill the purposes of the regulation.” 81 Fed. Reg. (April 29, ). BSEE will evaluate the specific conditions and BOP performance on a case-by-case basis (e.g., specific well conditions, operations, or equipment) to determine whether to require more frequent testing. This approach – reflected in provisions throughout Part 250 – is essential to provide the flexibility and discretion necessary to ensure that the purposes of the regulations are fulfilled in specific cases. This language is identical to the longstanding language found at former section § 250.447(b), and BSEE is unaware of any significant concerns raised by operators in connection with the District Managers’ exercise of this authority.
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