OFITE is excited to launch the OFITE Automated System (OASys). OASys is an innovative solution for the real-time measurement and reporting of drilling fluid properties. All three instruments included in OASys sit on the rig where they can sample the drilling fluid directly. The measurements are then sent to the rig data information system where it is used for simple real time calculations for predicting hole cleaning efficiency and ECD at total depth. This data is then available to be viewed through the rig data information system by the Driller and other personnel at the wellsite as well as remotely via the internet or smart phone apps.
Recent advances in drilling technology have significantly increased the average rate of penetration of a typical well. In the time a sample is drawn, taken to the lab, and measurements reported, the bit may have drilled hundreds of feet from when the sample was drawn. The need for continuous and for frequent measurements is critical.
Oil drilling is complex. It combines many different technologies and disciplines. Rig teams today must have extensive knowledge of drilling fluid chemistry as well as testing equipment to effectively drill a well.
We are proud to host a drilling fluid training program, taught by industry experts, that covers all aspects of drilling fluids technology. This course emphasizes both theory and practical application, with both classroom lecture and hands-on laboratory exercises.
The Retort is designed to measure the percentage of oil, water, and solids in a sample of drilling fluid or cuttings. This percentage is crucial for controlling mud properties, such as rheology, density, filtration, and salinity. And knowing the solids content of your drilling mud is essential for evaluating viscosity control and solids control equipment.
The new Multi Unit Retort combines five 50 mL Retorts into a single unit. Each Retort has its own electronic temperature controller and an ergonomic stand for holding the receiver tube (also known as JP Tube). This compact design not only fits under a fume hood, but it also saves valuable and scarce bench space.
Oil drilling is complex. It combines many different technologies and disciplines. Rig teams today must have extensive knowledge of drilling fluid chemistry as well as testing equipment to effectively drill a well.
We are proud to host a drilling fluid training program, taught by industry experts, that covers all aspects of drilling fluids technology. This course emphasizes both theory and practical application, with both classroom lecture and hands-on laboratory exercises.
Excessive torque and drag is a common problem in the drill string. It can cause a variety of problems that negatively impact well efficiency. The primary cause of often mechanical friction between the wellbore and tubulars. The solution is usually to add lubricants to the drilling fluid.
Prior to choosing any lubricant, it is important to evaluate all available options to see which one lubricates the best and has the best chemical compatibility with the drilling fluid. The most direct test method involves determining the coefficient of friction of the base fluid and comparing it to the coefficient of friction with the lubricant.
OFITE is excited to be hosting a new drilling fluids training program at our facility in Houston, TX. Classes are led by David Breeden, a consultant with over 35 years of experience in all aspects of drilling fluids technology, marketing, R&D, and operations. He will be assisted by Larry Mitchell, who has over 20 years of experience with drilling fluid testing equipment and technology.
Drilling is a complex operation requiring the combination of different technologies and disciplines. Today’s drilling personnel must have a working knowledge of drilling fluids to effectively drill a well. This course covers all aspects of drilling fluids technology, emphasizing both theory and practical application. Hands-on laboratory exercises are included.
A new partnership will see US-based OFI Testing Equipment, Inc. handle global distribution for monitoring specialists Salunda Limited’s hand-held drilling fluid measurement instrument, MudChecker.
Filtration testing is critical to understanding the effectiveness of a drilling mud system. Excess fluid loss can cause costly damage and drilling delays. Yet most filtration tests do not provide a complete picture of what it happening downhole. Static filtration represents only a part of drilling activity.
For most of a drilling operation, drilling fluid is circulating inside the wellbore. To understand how the movement of the fluid through the annulus affects filtration, you need a dynamic filter press.
The Retort measures the percentage (%) of oil, water, and solids in a sample of drilling fluid or cuttings. The results from a Retort test are essential to properly controlling mud properties such as rheology, density, filtration, and salinity. It is also important for evaluating viscosity control and solids control equipment.
Retort Kits have historically been large and bulky, taking up valuable laboratory space. The OFITE Multi Unit Retort combines five 50 mL Retort units into a single enclosure with a single electrical inlet. It saves space on the counter and only uses one electrical outlet. It also features a convenient stand for 50 mL Receiver Tubes (JP Tubes) and independent temperature control for each unit. The included software records and graphs the temperature of each unit over time.
The lubricating properties of drilling fluids are an important factor in well design. Deviated holes are particularly susceptible to excess drag between the drill string and casing. Serious casing wear can also occur in deep and ultra-deep wells and is further complicated by tripping in and out of the hole.
The challenge for mud engineers is to design a drilling fluid system that adequately lubricates the drill string without compromising other physical properties such as density, rheology, and filtration. To test the drilling fluid, engineers use a specially designed Lubricity Tester. This instrument simulates the rotation of the drill string and the pressure of the drill pipe against the casing. A stationary block is pressed against a rotating ring while both are submerged in the test fluid. The control board measures the torque necessary to turn the ring at a constant speed and converts that into the coefficient of friction.
Shale swelling is a major cause of wellbore instability. It can lead to a variety of problems, such as hole sloughing, pipe drag, bit balling, stuck pipe, or other “gumbo” related issues. Shale swelling is caused by clay (one of the major components of shale) absorbing water, usually from drilling fluid. The proper drilling fluid additives can mitigate shale swelling and prevent the loss of the entire drilling operation.
The OFITE Dynamic Linear Swellmeter measures the interaction between drilling fluids and mineral samples containing clays. This instrument can test up to four (expandable to eight) samples simultaneously and compare the results over time. Each test consists of a cylindrical wafer of compressed bentonite, rev dust, or downhole sample. The wafer is constrained around its circumference and exposed to fluid. As the clay reacts to the fluid, the wafer can only expand linearly. A Linear Variable Displacement Transducer (LVDT) measures the expansion of the water while the software tracks the percent of swelling over time. Each station includes independent heating and stirring.
Corrosion costs the drilling industry billions of dollars every year. Drill pipe, casing, and downhole tools are particularly vulnerable. To measure the corrosive properties of drilling and completion fluids, the industry uses corrosion rings and coupons. These are typically placed in the drill string and exposed to fluids during drilling operations. But sometimes more advanced testing is necessary.
The OFITE HTHP Corrosion Tester is designed to test the corrosive properties of fluids under elevated temperature and pressure in a laboratory setting. It can test four samples at a time at up to 400°F and 5,000 psi. The controlled environment of the lab makes it easier to control variables and get more repeatable results.
The Model 800 Viscometer has been around for years. It’s the workhorse of laboratory and field rheological testing. But why is it so popular? Why do so many people prefer it to the competition?
A lighted dial. It may not seem like much, but the tiny light inside the case illuminates the dial and makes it much easier to read. It is especially helpful in situations where ambient lighting is less than optimal. Whether it’s the glare from the sun or the gloom of a dark lab, the dial is always easy to read.
Universal voltage. All of the electrical components of the Model 800 operate exclusively on DC power. What does that mean to you? It means you can plug it in almost anywhere. The included power supply accepts between 100 and 240 volts of AC power. But the best part is the frequency. Whether you are operating on 50 Hz or 60 Hz, the power supply converts it to DC. We even offer a special 12 volt adapter for use in the cigarette lighter in your car or truck.
Threaded rotor. Have you ever run a test with a wobbly rotor? The rotor on the Model 800 is threaded. It mechanically attaches to the unit the same way every time. And it stays tight throughout the entire test.
No gearbox. Gears are complicated and messy. They wear out easily and they are prone to jamming and locking. The model 800 has no gear box. It’s just a motor and a belt. There’s no need to switch gears to change speeds; simply turn the knob. And it’s much easier to maintain and repair. Fewer moving parts means fewer problems to fix.
Speed control. The Model 800 uses a stepper motor to drive the rotor. Stepper motors have very precise speed control. While you are testing, the motor control board is constantly monitoring the speed and making adjustments. So you always know that your rotor is turning at the right speed.
Extra speeds. They say less is more. But at OFITE, we disagree. We believe more is more. So instead of offering only 6 speeds, our viscometer offers 8. The standard speeds of 600, 300, 200, 100, 6, and 3 RPM are suitable for most testing on drilling fluids. But for testing cement you need two extra speeds: 60 and 30 RPM. By including all 8 speeds, the Model 800 becomes a more versatile instrument.
Have you tried the Model 800 Viscometer yet? If not, you are missing out. Check the product page for more information or to place an order.
Times are tough in the oil patch. Staffing is reduced, budgets are cut, and approval processes are tightened. It is harder than ever to keep your lab equipped with the latest technology. But now is when it’s most important. We can help.
OFITE is now offering a new equipment lease program. Our goal is to offer a selection of instruments at monthly rates that fall below your capital expenditure limit.
Excessive torque and drag (ETD) is a common drilling problem, especially in extended-reach wells. ETD can cause lower penetration rates, increased hook-load, damage to downhole tubulars, and failure to reach target zones. While it can have many causes, mechanical friction between the wellbore and tubulars is often to blame. An effective and economical way to reduce mechanical friction is to add lubricating agents to the drilling fluid.
Before choosing a lubricant, it is important to test several options to determine which has the best lubricating properties and chemical compatibility with the drilling fluid. Performance testing involves determining the coefficient of friction (Cf) of the base drilling fluid and comparing it to the Cf with each additive.
Many drilling problems can be traced to the interaction between shale rock materials and drilling fluids. Testing the characteristics of the shale is the first step in developing an appropriate drilling fluid system that will be less reactive and cause fewer problems. One of these characteristics is hardness. Shale hardness can be related to the inhibitive properties of the drilling mud. When shale interacts with a fluid, water will often adsorb, the shale will swell, and fine particles will disperse. These can then reduce the compressive strength or cause the shale to spall or fracture, leading to significant wellbore stability problems. In addition, soft and/or sticky cuttings can cause mud rings, sticking problems, and bit balling.
The Bulk Hardness Tester (#150-87) was designed to evaluate the hardness of a shale sample after it has been exposed to a drilling fluid. In the test, the operator uses a torque wrench attached to a threaded piston to extrude the sample through a perforated plate. The torque required for each turn is recorded and evaluated. The change in torque during the test provides valuable information about the characteristics of the sample. Harder samples will require more torque, while software sample will require less.
The flow-back characteristics of drill-in fluids are critical to the productivity of a well. If the fluid plugs the production screen, it will not only slow down production, but it could also lead to screen erosion and costly remediation. But test flow-back has always been slow and expensive, often delaying rig operations for days or weeks while samples are shipped back to the lab.
With the Production Screen Tester (PST), you can now run flow-back tests right at the rig site with samples of the actual production screen being used down hole. The test is similar to the standard API filter press. You assemble the test cell with the screen sample at the bottom. After filling the cell with fluid, apply pressure to the top and open the valve at the bottom. The test will quickly show whether the screen and fluid are compatible.
Traditional filtration testing has always been limited by testing static conditions. Yet most of the time, drilling fluid is circulating through the wellbore. The movement of the fluid can have significant effects on the filter cake that are not measured by static filtration tests.
The OFITE Dynamic HTHP Filter Press (#170-95) is designed to correct this oversight. A shaft and paddle extend down into the test cell and circulate the fluid during a test. The speed is adjustable, and the motor can be started and stopped periodically to better simulate drilling conditions.
After the success of our Advanced Four-Unit HTHP Filter Press for 175 mL cells, we have developed a new version. This one is a two-unit model that accepts 500 mL filter press cells. Each cell has a separate electronic temperature control and two separate pressure regulators (drive pressure and back pressure). This allows independent heating and pressurization, while sharing a single power source.
This unit is ideal for high-volume laboratory testing. While test cells are sold separately, it does include all other accessories necessary to run a test (back pressure receivers, hoses, manifold blocks, graduated cyliners, filter paper, etc.
Any instrument that operates at elevated temperatures and pressures creates a safety concern in the lab. HTHP filter press cells are no different. The traditional design, with its six locking screws around the cap, has been known to trap pressure and become a safety risk.
OFITE has designed a new cell with safety in mind. This modular design is much safer and more convenient. The two-piece cap is threaded, and cannot be opened while the cell is pressurized. And interchangeable caps make it easy to reconfigure the cell for testing with different filter media (filter paper, ceramic disks, or cement screens) with a single cell body.
Excessive torque and drag (ETD) is a common drilling problem, especially in extended-reach wells. ETD can cause lower penetration rates, increased hook-load, damage to downhole tubulars, and failure to reach target zones. While it can have many causes, mechanical friction between the wellbore and tubulars is often to blame. An effective and economical way to reduce mechanical friction is to add lubricating agents to the drilling fluid.
Many drilling problems can be traced to the interaction between shale rock materials and drilling fluids. Testing the characteristics of the shale is the first step in developing an appropriate drilling fluid system that will be less reactive and cause fewer problems. One of these characteristics is hardness. Shale hardness can be related to the inhibitive properties of the drilling mud. When shale interacts with a fluid, water will often adsorb, the shale will swell, and fine particles will disperse. These can then reduce the compressive strength or cause the shale to spall or fracture, leading to significant wellbore stability problems. In addition, soft and/or sticky cuttings can cause mud rings, sticking problems, and bit balling.
The flow-back characteristics of drill-in fluids are critical to the productivity of a well. If the fluid plugs the production screen, it will not only slow down production, but it could also lead to screen erosion and costly remediation. But test flow-back has always been slow and expensive, often delaying rig operations for days or weeks while samples are shipped back to the lab.
Traditional filtration testing has always been limited by testing static conditions. Yet most of the time, drilling fluid is circulating through the wellbore. The movement of the fluid can have significant effects on the filter cake that are not measured by static filtration tests.
After the success of our 
Any instrument that operates at elevated temperatures and pressures creates a safety concern in the lab. HTHP filter press cells are no different. The traditional design, with its six locking screws around the cap, has been known to trap pressure and become a safety risk.