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Where to Place an Offshore Platform

Marine

When a major oil and gas operator wanted a new concrete gravity based platform placed in their existing subsea field, they asked us to figure out where to put it. At first it may seem like an easy task, pick a nice flat piece of seabed and job done. It is not that simple, however, and it took a multi-disciplinary team to get the optimum solution. Like all engineering issues, it is all about weighing the trade-offs between alternatives. Factors to consider in the placement of an offshore platform include drilling and completion costs, subsea infrastructure, and environmental impact, to name a few. These factors will impact the longer term viability of an offshore asset and it’s overall operability as infrastructure is added in the field. The drilling and completion costs are the most obvious to have be directly impacted by the surface position of an offshore platform. Here the overall drill and complete cost, as well as ability to reach geologic targets is based on the surface location of the platform, i.e. the starting surface location for all wells. Typically, platform placement is as close to the “center” of the pool as possible to enable the easiest options to access all parts of the structure, however, factors such as the desire to have horizontal completions, specific azimuths through a stress field, or a secondary geologic prospect, may move the platform from the “default” bullseye position. It is important to have an asset development plan from subsurface available (as mature as possible), to plan completions and trajectories for potential platform positions.

Where to Place an Offshore Platform

Marine

When a major oil and gas operator wanted a new concrete gravity based platform placed in their existing subsea field, they asked us to figure out where to put it. At first it may seem like an easy task, pick a nice flat piece of seabed and job done. It is not that simple, however, and it took a multi-disciplinary team to get the optimum solution. Like all engineering issues, it is all about weighing the trade-offs between alternatives. Factors to consider in the placement of an offshore platform include drilling and completion costs, subsea infrastructure, and environmental impact, to name a few. These factors will impact the longer term viability of an offshore asset and it’s overall operability as infrastructure is added in the field. The drilling and completion costs are the most obvious to have be directly impacted by the surface position of an offshore platform. Here the overall drill and complete cost, as well as ability to reach geologic targets is based on the surface location of the platform, i.e. the starting surface location for all wells. Typically, platform placement is as close to the “center” of the pool as possible to enable the easiest options to access all parts of the structure, however, factors such as the desire to have horizontal completions, specific azimuths through a stress field, or a secondary geologic prospect, may move the platform from the “default” bullseye position. It is important to have an asset development plan from subsurface available (as mature as possible), to plan completions and trajectories for potential platform positions.

How does a rod pump work?

Completions

The familiar pumpjack can be found around the world in oilfields from Texas to Beverly Hills to France. Why are pumpjacks so popular? Why are pumpjacks the go-to technology for the oil and gas industry? In short, pumpjacks (and rod pumps) are an efficient, simple and reliable means of pumping fluid from the subsurface. The pumpjack translates circular motion from an electric or gas engine into an up and down motion of a steel rod string. As the pumpjack motor rotates, it causes the walking beam (and horses head) of the pumpjack to move up and down. Weights are placed on the arms of the pumpjack and positioned to balance the weight of steel of the sucker rods. This reduces the amount of energy required to drive the pumpjack. The rods are pieces of steel (or occasionally fiberglass) which are threaded together to form a long steel pin which travels up and down the length of the well inside the tubing. At the end of the rod string is a pump barrel containing the pump components and the barrel is held in place in the tubing by a pump seating nipple. The pump is seated in the tubing and consists of two check valves. The travelling valve is connected to the sucker rods at the bottom of a plunger, and the standing valve is at the bottom of the pump barrel. The Traveling valve is so named because it travels, or moves, and the standing valve always stays in place as part of the pump barrel. The check valves of both these valves react to the pressure change seen in the pump barrel between the plunger and the standing valve.

How does a rod pump work?

Completions

The familiar pumpjack can be found around the world in oilfields from Texas to Beverly Hills to France. Why are pumpjacks so popular? Why are pumpjacks the go-to technology for the oil and gas industry? In short, pumpjacks (and rod pumps) are an efficient, simple and reliable means of pumping fluid from the subsurface. The pumpjack translates circular motion from an electric or gas engine into an up and down motion of a steel rod string. As the pumpjack motor rotates, it causes the walking beam (and horses head) of the pumpjack to move up and down. Weights are placed on the arms of the pumpjack and positioned to balance the weight of steel of the sucker rods. This reduces the amount of energy required to drive the pumpjack. The rods are pieces of steel (or occasionally fiberglass) which are threaded together to form a long steel pin which travels up and down the length of the well inside the tubing. At the end of the rod string is a pump barrel containing the pump components and the barrel is held in place in the tubing by a pump seating nipple. The pump is seated in the tubing and consists of two check valves. The travelling valve is connected to the sucker rods at the bottom of a plunger, and the standing valve is at the bottom of the pump barrel. The Traveling valve is so named because it travels, or moves, and the standing valve always stays in place as part of the pump barrel. The check valves of both these valves react to the pressure change seen in the pump barrel between the plunger and the standing valve.

Contracting Strategies for E&P Companies

Subsea

The oil and gas industry is more dynamic than ever but the demands on a limited number of people resources continue to increase. The traditional approach of hiring and training staff is becoming ineffective as the current workforce is increasingly mobile and investing in training and development provides limited return as the frequency of people changing employers increases. The popularity of contracting technical and project management among oil and gas companies continuously increases and new contracting arrangements are being created. It is commonplace for a company to hire a person to fill a role in an organization without providing a long-term employment contract but a fixed-term assignment. Referred to as an advisor, 2nd party labor, or in-house support, this arrangement requires active recruitment and management as an employee but typically without the training requirements. This can be a short-term solution but has a risk of creating a gap in the organization if the specific person chooses other employment. However, given the transient nature of employees, the commitments, obligations, and potential risks are very similar Occasionally a company has a short-term need for a specific task or project and the best fit is a skilled person who is contracted directly. This "Classic-Consulting" model is driven by finding the correct skill set and provides the flexibility for the contracted person to start and stop when tasks are complete. It is normal for the specific person to be used repeatedly, but works for others during "down-time". This provides oil and gas companies with flexibility on work commitment while still maintaining a high degree of control over the day to day activities.

Contracting Strategies for E&P Companies

Subsea

The oil and gas industry is more dynamic than ever but the demands on a limited number of people resources continue to increase. The traditional approach of hiring and training staff is becoming ineffective as the current workforce is increasingly mobile and investing in training and development provides limited return as the frequency of people changing employers increases. The popularity of contracting technical and project management among oil and gas companies continuously increases and new contracting arrangements are being created. It is commonplace for a company to hire a person to fill a role in an organization without providing a long-term employment contract but a fixed-term assignment. Referred to as an advisor, 2nd party labor, or in-house support, this arrangement requires active recruitment and management as an employee but typically without the training requirements. This can be a short-term solution but has a risk of creating a gap in the organization if the specific person chooses other employment. However, given the transient nature of employees, the commitments, obligations, and potential risks are very similar Occasionally a company has a short-term need for a specific task or project and the best fit is a skilled person who is contracted directly. This "Classic-Consulting" model is driven by finding the correct skill set and provides the flexibility for the contracted person to start and stop when tasks are complete. It is normal for the specific person to be used repeatedly, but works for others during "down-time". This provides oil and gas companies with flexibility on work commitment while still maintaining a high degree of control over the day to day activities.

The Pulling Tool that ALMOST Fit

Completions

When you are planning a wireline job no detail is too small. I had planned a job in offshore Australia where the job was fairly simple - it was just pull gas lift valve out of the completion. It was a single valve installed many years ago and I just needed to pull the valve and set a dummy. I had reviewed the well file and the only thing that stood out was the lack of activity on these wells since the wells had been drilled there had been no workovers or well interventions completed after 20 years. As with most well interventions there was limited time to prepare, and this was a fairly straight forward job. Luckily the pulling tool was locally available, as well as the slickline crew (meaning they were mostly in the same country), and equipment. We needed a large bore kickover tool but this was in stock and available so it looked like it was going to be fairly easy this time. I lined up a supervisor who used to work on the production side on the same platform, so things were coming together nicely. The oil industry is really good at adopting a technology (once it is proven) and then applying it to solve issues specific to their specific environment. However, the industry is not so fast to adopt new ways of doing things which is reasonable considering the safety and financial risks involved in the business we are in. When cost estimating the first of any type of work in an asset or area, the actuals will almost always be higher than average, but as lessons are learned and the work becomes standardized, efficiencies appear that will drive costs down and increase asset value…but, you have to start somewhere. An extreme example of this would be pulling a gas lift dummy valve – probably one of the most common activities in a platform-based oil well, however, if it has not been done on a platform, asset, company, area, before, it can be met with a healthy amount of skepticism. This was a standard operation and all the pieces were coming together. I have always enjoyed using a GANTT chart and seeing what is on the critical path when planning a project execution. No-one wants to be on the critical path, but everyone will use every possible day they can get before becoming the long lead item. On this job the critical path was the availability of the slickline unit, so there was time to look at other aspects. This gave time to have a thorough review of the program.

The Pulling Tool that ALMOST Fit

Completions

When you are planning a wireline job no detail is too small. I had planned a job in offshore Australia where the job was fairly simple - it was just pull gas lift valve out of the completion. It was a single valve installed many years ago and I just needed to pull the valve and set a dummy. I had reviewed the well file and the only thing that stood out was the lack of activity on these wells since the wells had been drilled there had been no workovers or well interventions completed after 20 years. As with most well interventions there was limited time to prepare, and this was a fairly straight forward job. Luckily the pulling tool was locally available, as well as the slickline crew (meaning they were mostly in the same country), and equipment. We needed a large bore kickover tool but this was in stock and available so it looked like it was going to be fairly easy this time. I lined up a supervisor who used to work on the production side on the same platform, so things were coming together nicely. The oil industry is really good at adopting a technology (once it is proven) and then applying it to solve issues specific to their specific environment. However, the industry is not so fast to adopt new ways of doing things which is reasonable considering the safety and financial risks involved in the business we are in. When cost estimating the first of any type of work in an asset or area, the actuals will almost always be higher than average, but as lessons are learned and the work becomes standardized, efficiencies appear that will drive costs down and increase asset value…but, you have to start somewhere. An extreme example of this would be pulling a gas lift dummy valve – probably one of the most common activities in a platform-based oil well, however, if it has not been done on a platform, asset, company, area, before, it can be met with a healthy amount of skepticism. This was a standard operation and all the pieces were coming together. I have always enjoyed using a GANTT chart and seeing what is on the critical path when planning a project execution. No-one wants to be on the critical path, but everyone will use every possible day they can get before becoming the long lead item. On this job the critical path was the availability of the slickline unit, so there was time to look at other aspects. This gave time to have a thorough review of the program.

D6 Dozer

Construction

A D6 bulldozer is a type of heavy construction equipment that is designed for use in a wide range of earthmoving and grading applications. It is typically used for tasks such as clearing land, grading, and digging trenches. The D6 is a medium-sized bulldozer that is manufactured by Caterpillar, one of the leading manufacturers of construction equipment. The D6 bulldozer features a durable steel frame and undercarriage that is designed to withstand the demanding conditions of heavy construction work. The frame and undercarriage are built to withstand high loads and stresses and are designed to provide a stable and durable platform for the bulldozer's attachments and components. The D6 bulldozer is powered by a diesel engine that provides a high level of power and performance. The engine is designed to provide a high level of fuel efficiency and low emissions, making it well-suited for use in a wide range of environments.

D6 Dozer

Construction

A D6 bulldozer is a type of heavy construction equipment that is designed for use in a wide range of earthmoving and grading applications. It is typically used for tasks such as clearing land, grading, and digging trenches. The D6 is a medium-sized bulldozer that is manufactured by Caterpillar, one of the leading manufacturers of construction equipment. The D6 bulldozer features a durable steel frame and undercarriage that is designed to withstand the demanding conditions of heavy construction work. The frame and undercarriage are built to withstand high loads and stresses and are designed to provide a stable and durable platform for the bulldozer's attachments and components. The D6 bulldozer is powered by a diesel engine that provides a high level of power and performance. The engine is designed to provide a high level of fuel efficiency and low emissions, making it well-suited for use in a wide range of environments.

Blowout and Oil Spill Modelling

Drilling

When planning an offshore well (or any well, for that manner) the well construction process is focused on safely executing the drilling and completion of the well. However, in the event of a well control incident, an estimation of the worst case discharge from an offshore well is required. In the United States this is mandated by the document BOEM NTL No. 2015-01, which supersedes the previous BOEM NTL No. 2010-N06. According to NTL-No-2015-N01, the operator has to submit a plan which describes the scenario of the worst case blowout potential during the well construction. This includes the flowrate from the drilled zones, the potential for bridging off, the availability of a rig to drill a relief well and the time it will take to intersect the subject well with the relief well. According to the SPE guidance for complying with BOEM NTL No. 2010-N06 (from September, 2010) the procedure (in brief) is as follow; To determine the Worst Case discharge scenario, all potential hydrocarbon-bearing formations in each hole section will have an absolute open flow calculated, and the hole section with the highest AOF will be used. The time to drill a relief well for this hole section is to be calculated. A production profile (including commingling and decline) is created, and the flow rate over the relief well time is then used to determine the worst case oil spill volume. The time to drill a relief well includes the contracting, mobilization, and potential sidetracking to intersect the original wellbore.

Blowout and Oil Spill Modelling

Drilling

When planning an offshore well (or any well, for that manner) the well construction process is focused on safely executing the drilling and completion of the well. However, in the event of a well control incident, an estimation of the worst case discharge from an offshore well is required. In the United States this is mandated by the document BOEM NTL No. 2015-01, which supersedes the previous BOEM NTL No. 2010-N06. According to NTL-No-2015-N01, the operator has to submit a plan which describes the scenario of the worst case blowout potential during the well construction. This includes the flowrate from the drilled zones, the potential for bridging off, the availability of a rig to drill a relief well and the time it will take to intersect the subject well with the relief well. According to the SPE guidance for complying with BOEM NTL No. 2010-N06 (from September, 2010) the procedure (in brief) is as follow; To determine the Worst Case discharge scenario, all potential hydrocarbon-bearing formations in each hole section will have an absolute open flow calculated, and the hole section with the highest AOF will be used. The time to drill a relief well for this hole section is to be calculated. A production profile (including commingling and decline) is created, and the flow rate over the relief well time is then used to determine the worst case oil spill volume. The time to drill a relief well includes the contracting, mobilization, and potential sidetracking to intersect the original wellbore.

Wat veroorzaakte de druk, dat maar bleef stijgen?

Process Equipment

Het vinden van de juiste materialen op het juiste moment kan een uitdaging zijn wanneer je druk bezig bent met produceren. Zoals bij de meeste bedrijven, hebben wij onze standaard inkoopprocedures die meestal prima werken, en gelukkig was onze inkoopafdeling ook redelijk begripvol wanneer er problemen opdoken (wat altijd leek te gebeuren om 1 uur 's nachts op zaterdag, om de een of andere reden). Het onderhoud was vrij goed verlopen, iets langer dan gepland, maar er was niets groots gevonden tijdens de inspecties. De fabriek was helemaal afgerond en het projectteam had zijn werk voltooid. En het productieteam was op dat moment net bezig met het opstarten, toen de compressoren uitsloegen door hoge druk.

Wat veroorzaakte de druk, dat maar bleef stijgen?

Process Equipment

Het vinden van de juiste materialen op het juiste moment kan een uitdaging zijn wanneer je druk bezig bent met produceren. Zoals bij de meeste bedrijven, hebben wij onze standaard inkoopprocedures die meestal prima werken, en gelukkig was onze inkoopafdeling ook redelijk begripvol wanneer er problemen opdoken (wat altijd leek te gebeuren om 1 uur 's nachts op zaterdag, om de een of andere reden). Het onderhoud was vrij goed verlopen, iets langer dan gepland, maar er was niets groots gevonden tijdens de inspecties. De fabriek was helemaal afgerond en het projectteam had zijn werk voltooid. En het productieteam was op dat moment net bezig met het opstarten, toen de compressoren uitsloegen door hoge druk.

The SCSSSV Isolation Question

Completions

In some wells with surface controlled subsurface safety valves a landing nipple is used to lock and operate a wireline retrievable downhole safety valve. The wireline retrievable valve can be pulled to allow nearly full-bore access to the wellbore, however it is a question as to whether an isolation sleeve should be run or not. One of the key advantages for installing a wireline retrievable subsurface safety valve is that it can be pulled and allow larger tools to be run on wireline. However, the insert valve has to form a seal with the inside of the tubing in a safety valve landings nipple. This is achieved by running an upper and lower seal assembly made of chevron seals (or o-rings) which form a seal for the hydraulic oil in the control line to pressure up the safety valve. When wirelining, the wire will ride in a certain location (low side) and can create a groove in this sealing area. This groove can lead to the packing elements of the insert valve not forming a hydraulic seal and rendering the valve inoperable. In this particular well, there was a history of sand production, and the completion was more than 40 years old, which are both cause for concern when running slickline across a SCSSSV nipple profile. It was decided during job design to install an isolation sleeve across the landing nipple to prevent damaging the sealing profile.

The SCSSSV Isolation Question

Completions

In some wells with surface controlled subsurface safety valves a landing nipple is used to lock and operate a wireline retrievable downhole safety valve. The wireline retrievable valve can be pulled to allow nearly full-bore access to the wellbore, however it is a question as to whether an isolation sleeve should be run or not. One of the key advantages for installing a wireline retrievable subsurface safety valve is that it can be pulled and allow larger tools to be run on wireline. However, the insert valve has to form a seal with the inside of the tubing in a safety valve landings nipple. This is achieved by running an upper and lower seal assembly made of chevron seals (or o-rings) which form a seal for the hydraulic oil in the control line to pressure up the safety valve. When wirelining, the wire will ride in a certain location (low side) and can create a groove in this sealing area. This groove can lead to the packing elements of the insert valve not forming a hydraulic seal and rendering the valve inoperable. In this particular well, there was a history of sand production, and the completion was more than 40 years old, which are both cause for concern when running slickline across a SCSSSV nipple profile. It was decided during job design to install an isolation sleeve across the landing nipple to prevent damaging the sealing profile.

The hard hat is a symbol of hard work

Workover

The “hard boiled hat” was invented by Edward Bullard in 1919. A hardhat is a type of protective headgear that is worn by workers in the oil and gas industry to protect their head from falling objects, electrical hazards and other potential hazards that may occur on a drilling site. Hardhats are typically made of high-density polyethylene (HDPE) or other durable materials that can withstand impact and penetration. They are designed to provide a high level of protection to the head and face while allowing the worker to see and hear clearly. The typical hardhat used in oil drilling has several key components, including: • The shell: The shell is the outermost layer of the hardhat and is typically made of HDPE or other durable materials that can withstand impact and penetration. • The suspension system: The suspension system is the internal support system of the hardhat that holds it securely on the head and provides a comfortable fit. It is typically made of a combination of straps, webbing, and other materials that can be adjusted to fit the head snugly. • The headband: The headband is the internal band that sits on the forehead, helping to distribute the weight of the hardhat evenly around the head. • The ear muffs: Many hardhats have the option of adding earmuffs or earplugs to protect the worker from excessive noise. • The face shield: Some hardhats have the option of adding a face shield to protect the worker from flying debris and other hazards.

The hard hat is a symbol of hard work

Workover

The “hard boiled hat” was invented by Edward Bullard in 1919. A hardhat is a type of protective headgear that is worn by workers in the oil and gas industry to protect their head from falling objects, electrical hazards and other potential hazards that may occur on a drilling site. Hardhats are typically made of high-density polyethylene (HDPE) or other durable materials that can withstand impact and penetration. They are designed to provide a high level of protection to the head and face while allowing the worker to see and hear clearly. The typical hardhat used in oil drilling has several key components, including: • The shell: The shell is the outermost layer of the hardhat and is typically made of HDPE or other durable materials that can withstand impact and penetration. • The suspension system: The suspension system is the internal support system of the hardhat that holds it securely on the head and provides a comfortable fit. It is typically made of a combination of straps, webbing, and other materials that can be adjusted to fit the head snugly. • The headband: The headband is the internal band that sits on the forehead, helping to distribute the weight of the hardhat evenly around the head. • The ear muffs: Many hardhats have the option of adding earmuffs or earplugs to protect the worker from excessive noise. • The face shield: Some hardhats have the option of adding a face shield to protect the worker from flying debris and other hazards.

Frac'ing Basic

Workover

Hydraulic fracturing, or frac'ing is an effective mans of increasing recovery and production rate from an oil and gas well. This stimulation technique is used to increase the area oil and gas has to flow into a wellbore. Small diameter wells naturally become a choke point for fluid fow and by hydraulically fracturing the rock around the well, a more effective flow path can be opened up. The rock containing oil and gas is split (fractured) by applying hydraulic pressure. The pressure applied is high enough to exceed the tensile strength of the rock matrix, creating cracks in the rock. Fluid is also lost into the natural permeability of the rock and a viscous gel is used to reduce these losses. The fluid pressure and rate used to fracture the rock is accomplished by the use of pumps at surface. A well typically only requires one hydraulic fracturing treatment, so the pumping equipment is mobile and can be transported from well to well. In conventional frac'ing, the strength of the caprock (overlying geologic layers) and well construction (the steel and cement used in drilling the well) keeps the frac contained in the target zone. This is an important design consideration so the reservoir fluids stay in the original geologic horizon and don't leak off (into groundwater, for example).

Frac'ing Basic

Workover

Hydraulic fracturing, or frac'ing is an effective mans of increasing recovery and production rate from an oil and gas well. This stimulation technique is used to increase the area oil and gas has to flow into a wellbore. Small diameter wells naturally become a choke point for fluid fow and by hydraulically fracturing the rock around the well, a more effective flow path can be opened up. The rock containing oil and gas is split (fractured) by applying hydraulic pressure. The pressure applied is high enough to exceed the tensile strength of the rock matrix, creating cracks in the rock. Fluid is also lost into the natural permeability of the rock and a viscous gel is used to reduce these losses. The fluid pressure and rate used to fracture the rock is accomplished by the use of pumps at surface. A well typically only requires one hydraulic fracturing treatment, so the pumping equipment is mobile and can be transported from well to well. In conventional frac'ing, the strength of the caprock (overlying geologic layers) and well construction (the steel and cement used in drilling the well) keeps the frac contained in the target zone. This is an important design consideration so the reservoir fluids stay in the original geologic horizon and don't leak off (into groundwater, for example).

The Surprising Significance of Rocks

Drilling

I never thought much about rocks until I found myself standing in the midst of nature, like I’ve never seen before. As far as the eye could see, shale, limestone, and granite rocks of all shapes and sizes surrounded me, each with its own unique story to tell. It was humbling to realize that these unremarkable-looking rocks were the very foundation of our modern society, having been utilized in countless ways to enhance our way of life. Some were smooth and polished, while others were rough and jagged, hinting at the diverse range of processes that had formed them. As I looked in amazement at the different kinds of rocks around me, it struck me that each one possessed its own distinct properties, capable of transforming over time to create an entirely new type of rock. It was a mind-boggling thought, especially considering how integral these rocks were to our daily lives, from the granite countertops in our kitchens to the shale gas that heated our homes and the batteries that powered our devices.

The Surprising Significance of Rocks

Drilling

I never thought much about rocks until I found myself standing in the midst of nature, like I’ve never seen before. As far as the eye could see, shale, limestone, and granite rocks of all shapes and sizes surrounded me, each with its own unique story to tell. It was humbling to realize that these unremarkable-looking rocks were the very foundation of our modern society, having been utilized in countless ways to enhance our way of life. Some were smooth and polished, while others were rough and jagged, hinting at the diverse range of processes that had formed them. As I looked in amazement at the different kinds of rocks around me, it struck me that each one possessed its own distinct properties, capable of transforming over time to create an entirely new type of rock. It was a mind-boggling thought, especially considering how integral these rocks were to our daily lives, from the granite countertops in our kitchens to the shale gas that heated our homes and the batteries that powered our devices.

Wat veroorzaakte de druk, dat maar bleef stijgen?

Process Equipment

Het vinden van de juiste materialen op het juiste moment kan een uitdaging zijn wanneer je druk bezig bent met produceren. Zoals bij de meeste bedrijven, hebben wij onze standaard inkoopprocedures die meestal prima werken, en gelukkig was onze inkoopafdeling ook redelijk begripvol wanneer er problemen opdoken (wat altijd leek te gebeuren om 1 uur 's nachts op zaterdag, om de een of andere reden). Het onderhoud was vrij goed verlopen, iets langer dan gepland, maar er was niets groots gevonden tijdens de inspecties. De fabriek was helemaal afgerond en het projectteam had zijn werk voltooid. En het productieteam was op dat moment net bezig met het opstarten, toen de compressoren uitsloegen door hoge druk.

Wat veroorzaakte de druk, dat maar bleef stijgen?

Process Equipment

Het vinden van de juiste materialen op het juiste moment kan een uitdaging zijn wanneer je druk bezig bent met produceren. Zoals bij de meeste bedrijven, hebben wij onze standaard inkoopprocedures die meestal prima werken, en gelukkig was onze inkoopafdeling ook redelijk begripvol wanneer er problemen opdoken (wat altijd leek te gebeuren om 1 uur 's nachts op zaterdag, om de een of andere reden). Het onderhoud was vrij goed verlopen, iets langer dan gepland, maar er was niets groots gevonden tijdens de inspecties. De fabriek was helemaal afgerond en het projectteam had zijn werk voltooid. En het productieteam was op dat moment net bezig met het opstarten, toen de compressoren uitsloegen door hoge druk.

Slickline vs. Coiled Tubing

Workover

Well interventions can be highly profitable and there are a number of tools to use. Slickline and coiled tubing are the most commonly used and flexible equipment to diagnose and remediate well issues.. Slickline is perhaps the simplest well intervention tool. It is a single strand "piano wire" that due to it's smooth surface is able to have a packing seal directly on the wire, hence the "slick" term. Slickline is in the category of wireline which includes braided and electric line which has strands of wire wrapped together, creating spaces between the strands of wire which requires grease packing to create an effective seal (and hence not "slick"). Slickline can be truck or skid mounted for use on- or offshore and lightweight units can even be transported by helicopter. The wire is wrapped on a drum and a winch is used to run the wire in and out of the well using weights on the end of the wire. A variety of tools can be run on slickline to perform mechanical actions such as setting and pulling plugs, pressure gauges, or safety valves. It is referred to as a wireline which also includes braided line and electric line. Electronic timers can be used to deploy tools using triggers and battery-powered tools. Coiled tubing is also used through tubing and consists of a continuous pipe rolled on a drum with a swivel connection allowing the coil to run "slick" through a packoff and has the advantage of being able to pump through the inside of the coil.

Slickline vs. Coiled Tubing

Workover

Well interventions can be highly profitable and there are a number of tools to use. Slickline and coiled tubing are the most commonly used and flexible equipment to diagnose and remediate well issues.. Slickline is perhaps the simplest well intervention tool. It is a single strand "piano wire" that due to it's smooth surface is able to have a packing seal directly on the wire, hence the "slick" term. Slickline is in the category of wireline which includes braided and electric line which has strands of wire wrapped together, creating spaces between the strands of wire which requires grease packing to create an effective seal (and hence not "slick"). Slickline can be truck or skid mounted for use on- or offshore and lightweight units can even be transported by helicopter. The wire is wrapped on a drum and a winch is used to run the wire in and out of the well using weights on the end of the wire. A variety of tools can be run on slickline to perform mechanical actions such as setting and pulling plugs, pressure gauges, or safety valves. It is referred to as a wireline which also includes braided line and electric line. Electronic timers can be used to deploy tools using triggers and battery-powered tools. Coiled tubing is also used through tubing and consists of a continuous pipe rolled on a drum with a swivel connection allowing the coil to run "slick" through a packoff and has the advantage of being able to pump through the inside of the coil.

Bell 206 Helicopter

Transport

The Bell 206 is a single-engine, light helicopter that was first introduced in the 1960s and has been used for a variety of roles, including transportation, search and rescue, and aerial surveying. The helicopter is designed and manufactured by Bell Helicopter, a division of Textron Inc. The Bell 206 features a two-blade semi-rigid main rotor and a two-blade tail rotor. The main rotor is designed to provide lift and control, while the tail rotor is used to counter the torque produced by the main rotor and provide directional stability. The main rotor is made of aluminum, which makes it lightweight and durable. The rotor system is designed to provide a high level of performance and safety, and it is equipped with advanced vibration dampers to reduce noise and vibration.

Bell 206 Helicopter

Transport

The Bell 206 is a single-engine, light helicopter that was first introduced in the 1960s and has been used for a variety of roles, including transportation, search and rescue, and aerial surveying. The helicopter is designed and manufactured by Bell Helicopter, a division of Textron Inc. The Bell 206 features a two-blade semi-rigid main rotor and a two-blade tail rotor. The main rotor is designed to provide lift and control, while the tail rotor is used to counter the torque produced by the main rotor and provide directional stability. The main rotor is made of aluminum, which makes it lightweight and durable. The rotor system is designed to provide a high level of performance and safety, and it is equipped with advanced vibration dampers to reduce noise and vibration.

Hydraulic Cylinders

Construction

A hydraulic cylinder is a mechanical actuator that uses the power of pressurized hydraulic fluid to produce a force in a linear motion. It is commonly used in a wide range of industrial, mobile, and marine applications, such as construction equipment, manufacturing machinery, and marine propulsion systems. The hydraulic cylinder consists of several key components, including a cylinder barrel, a piston, a rod, and seals. The cylinder barrel is the outer tube of the cylinder, which contains the pressurized hydraulic fluid. The piston is a sliding cylinder that is located inside the cylinder barrel and is used to convert the pressure of the fluid into a linear force. The rod is connected to the piston and extends out of the cylinder, providing the linear motion of the cylinder. The seals are used to prevent leakage of the fluid between the cylinder barrel and the piston.

Hydraulic Cylinders

Construction

A hydraulic cylinder is a mechanical actuator that uses the power of pressurized hydraulic fluid to produce a force in a linear motion. It is commonly used in a wide range of industrial, mobile, and marine applications, such as construction equipment, manufacturing machinery, and marine propulsion systems. The hydraulic cylinder consists of several key components, including a cylinder barrel, a piston, a rod, and seals. The cylinder barrel is the outer tube of the cylinder, which contains the pressurized hydraulic fluid. The piston is a sliding cylinder that is located inside the cylinder barrel and is used to convert the pressure of the fluid into a linear force. The rod is connected to the piston and extends out of the cylinder, providing the linear motion of the cylinder. The seals are used to prevent leakage of the fluid between the cylinder barrel and the piston.

Sand in my Valve!

Completions

Sand production is a common problem in the oil and gas industry and can have significant impacts on the performance and reliability of a surface controlled sub-surface safety valve (SCSSV). Sand production occurs when sand particles are produced along with the oil or gas and can cause damage to the valve and its components, leading to failure. In this essay, we will discuss the effects of sand production on a SCSSV and some ways to prevent failure. One of the main effects of sand production on a SCSSV is erosion. Sand particles can cause abrasion to the valve body and its components, leading to corrosion and eventual failure. Sand particles can also accumulate in the valve body and cause obstructions, reducing its ability to function properly. This can lead to increased pressure and stress on the valve components, further increasing the likelihood of failure.

Sand in my Valve!

Completions

Sand production is a common problem in the oil and gas industry and can have significant impacts on the performance and reliability of a surface controlled sub-surface safety valve (SCSSV). Sand production occurs when sand particles are produced along with the oil or gas and can cause damage to the valve and its components, leading to failure. In this essay, we will discuss the effects of sand production on a SCSSV and some ways to prevent failure. One of the main effects of sand production on a SCSSV is erosion. Sand particles can cause abrasion to the valve body and its components, leading to corrosion and eventual failure. Sand particles can also accumulate in the valve body and cause obstructions, reducing its ability to function properly. This can lead to increased pressure and stress on the valve components, further increasing the likelihood of failure.

Everyone wants to do a good job or DEG Regeneration Drama

Process Equipment

I had just been put in charge of the Facilities Engineering department and I found the job great - working with lots of production, maintenance, and operations people. My manager came to me with an issue that a vendor had not done the work they were supposed to do, took the money for the job, delivered the wrong equipment, and refused to help commission and fix the system. The first step was to figure out what this project was all about. The company was using di-etheylene glycol (DEG) to carry corrosion inhibitor from the wells to the gas treatment facility, as well as binding any free water to avoid hydrates. At the facility the glycol was re-generated by heating the glycol to boil off the water from the glycol (returning it to Lean Glycol). The lean DEG was then returned to the field and re-injected at different wellsites. It was mandated two years previous that the existing DEG regeneration system did not meet standards and would have to be replaced with a new system. The first year this was agreed was a tough one in the industry, so it was almost immediately cut from the budget. The following year it was permitted to have study work done, but at a fraction of the required engineering cost. The year that it was scheduled to be installed, engineering began, and consultants were hired to execute the project and pressure was placed on the organization to get this now hyper-critical regulatory issue dealt with.

Everyone wants to do a good job or DEG Regeneration Drama

Process Equipment

I had just been put in charge of the Facilities Engineering department and I found the job great - working with lots of production, maintenance, and operations people. My manager came to me with an issue that a vendor had not done the work they were supposed to do, took the money for the job, delivered the wrong equipment, and refused to help commission and fix the system. The first step was to figure out what this project was all about. The company was using di-etheylene glycol (DEG) to carry corrosion inhibitor from the wells to the gas treatment facility, as well as binding any free water to avoid hydrates. At the facility the glycol was re-generated by heating the glycol to boil off the water from the glycol (returning it to Lean Glycol). The lean DEG was then returned to the field and re-injected at different wellsites. It was mandated two years previous that the existing DEG regeneration system did not meet standards and would have to be replaced with a new system. The first year this was agreed was a tough one in the industry, so it was almost immediately cut from the budget. The following year it was permitted to have study work done, but at a fraction of the required engineering cost. The year that it was scheduled to be installed, engineering began, and consultants were hired to execute the project and pressure was placed on the organization to get this now hyper-critical regulatory issue dealt with.