|Theme||Visible||Selectable||Appearance||Zoom Range (now: 0)|
Pragma is bringing the industry’s first 3D metal printed, ultrahigh expansion bridge plug to market, the Aberdeen-based company said in a press release. Its patented M-Bubble bridge plug has successfully completed final lab testing and is due to begin field trials by the end of 2020. Initially targeted at both the plug-and-abandonment (P&A) sector and water shutoff applications, the first M-Bubble addresses a gap in the market for a lower-cost, fast-turnaround, permanent plugging solution, with a high pressure differential (3,000 psi) capability, the company said. The plug can be set without additional cement to save rig time and “waiting-on-cement” time, which can accumulate significant savings for the operator, especially in deeper, extended-reach wells. It also provides barrier-integrity reassurance when there is the possibility of a poor cement bond or cement channeling occurring on the high side of deviated wells, the company added.
Chemistry solutions and equipment technologies company ChampionX is combining its research and development capabilities with nanotechnology company Modumetal, and its materials and processes, in an exclusive collaboration agreement to drive production-related technology developments. The collaboration will introduce ChampionX’s Norris rod couplings coated with Modumetal nanolaminate technology.
Pressure vessels used in the petrochemical industry inspected manually by people working inside the vessels, which is a very time consuming operation in a potentially
ADNOC CEO has launched Oil & Gas 4.0 in the year 2019 and stated that Oil and Gas 4.0 means rethinking how our industry adopts and applies technology, connects with non-traditional partners, shows environmental leadership and most importantly attracts and retains talent. We as, ADNOC Gas Processing Technical Services Engineering division inspired by the ADNOC CEO's speech and adopted introduction of innovative technology in every sphere of technical field. We choose to explore the possiblitity of the introduction of drones, robotics and other technology that are increasing efficiency and productivity while protecting the environment in all stages of energy production.
ADNOC Gas Processing has conducted Corrosion and Inspection forum in 2019 as a part of digitasation by inviting leaders in the NDT field to show cause the available latest technology. During the forum, we could explore several advanced NDT techniques including Drones, robotics, helmet mounted cameras and wireless UT thikness monitoing devices. With the advancement of technology, drones once predominantly used for patrolling highways and delivery of the foods were used extensively for visual inspection of elevated structures (stacks) and robotics are used to inspection pressure vessels and storage tanks with out necessity of man entry and thus avaiding the human exposure to the hazdous evironments.
The objective of this paper is to showcase the successful and innovative troubleshooting data analysis techniques in one of the gas compression systems in upstream gas oil separation plants (GOSP-A). The gas compression system using gas compressors, dry gas seal systems and due point controls is used in almost all of upstream operation.
These proven data analysis techniques were used to tackle major and chronic issues associated with gas compression system operation that lead to excessive flaring, mechanical seal failures, and off-specification products. Dry Gas mechanical seals are an important key element in gas compression and its lifetime represents a concern to the operation personnel. Most gas compression systems have a mechanical seal lifetime of 2 years which in some cases limit production, increase the potential of unnecessary flaring and increase OPEX significantly.
In this paper, comprehensive data analysis of the potential root causes that aggravate undesired premature mechanical seal failures and off-specification gas products will be discussed along with solutions to minimize expected impact. For example, improper gas conditioning that feeds dry gas mechanical seals increase the risk of premature failures. Additionally, improper product specification in some applications have been found to promote seal failures and incur additional flaring which is both costly and environmentally undesirable. In addition, after extensive analysis improper operation practices during compressor startups, steady state operation and gas conditioning have been linked with premature compressor failures, product off spec and safety device failures.
The field trial proved the effectiveness of the proposed innovative troubleshooting data analysis techniques in reinstating the gas compression unit in GOSP-A to its recommended design conditions, eliminated compressors and mechanical seal failures and avoided the off-specification products at the lowest operating cost. This innovative technique was based on deep and extensive process data analysis, evaluating operating and design data, reviewing international standards, benchmarking against other facilities, process simulation using Hysys, and finally the actual field trial.
A field trial was conducted for deoiling produced water at a Saudi Aramco GOSP. The objective of the field trial was to prove the concept of the centrifugal separator and test its capabilities to deoil produced water at varying feed rates and inlet concentrations.
The centrifuge was fed from the common water outlet line of a gravity water oil separator. Samples were taken for oil-in-water measurement using ASTMD7678. The testing covered various flowrates and inlet concentrations, which were adjusted by manipulating upstream conditions. Several parameters were used to determine the adequacy:
Outlet oil-in water content (expected significantly less than 50 mg/l) and sufficiently high separation efficiencies to achieve the specification Unit downtime due to trip and failure of the unit and due to filter/screen cleaning and replacement
Outlet oil-in water content (expected significantly less than 50 mg/l) and sufficiently high separation efficiencies to achieve the specification
Unit downtime due to trip and failure of the unit and due to filter/screen cleaning and replacement
The feed rate was adjusted by manipulating a valve at the inlet of the separator. A sample at the inlet and outlet of the separator was taken at each flowrate and condition as per the test guideline. It was noticed that inlet oil-in-water concentrations to separator were mostly on-spec, with only a few of them above 100 mg/l, as a result of temporarily lowering the dehydrator interface level for the the trial.
The following observations can be made based on the test run data:
The outlet oil-in water met the spec, far exceeding expectations Oil in water removal efficiency varied significantly, varying from 65-90% depending on rate and inlet concentration There were no issues in terms of unit downtime related to trips and filter/screen plugging
The outlet oil-in water met the spec, far exceeding expectations
Oil in water removal efficiency varied significantly, varying from 65-90% depending on rate and inlet concentration
There were no issues in terms of unit downtime related to trips and filter/screen plugging
This was the first trial for a Saudi Aramco field. The process was applied to a facility with tight emulsions and a challenging environment that requires a highly efficient deoiling process, which the centrifugal separation has proven to be. Potential applications for produced water treatment and waste water handling can be derived from the field trial result.
The application of big data analytics, artificial intelligence, and machine learning to solving challenging problems is ever-increasing in the oil and gas industry. These techniques have already been proven to be powerful tools that can not only improve safety and reliability but can also provide more consistent and accurate decision-making capabilities as compared to conventional methods. This paper will detail a real-world application of big data analytics and machine learning to the tubular connection make-up process, realizing significant benefits over traditional human-evaluated methods. While the focus of the paper will be on a single application, similar approaches may be beneficial to other applications and other industries, achieving similar benefits.
For the upstream industry, where improvement in efficiency or production can drive significant financial results, there is no question that the size of the digital prize is huge. This paper describes the development and field trials of a cloud-connected, wireless intelligent completion system that enables long-term monitoring and interval control to enhance production management by connecting the user wirelessly from the desktop to downhole inflow-control valves. The combination of digital technologies will enable Chevron—and, eventually, other companies—to process, visualize, interpret, and glean insights from multiple data sources, the companies said. Equinor, Microsoft, and Halliburton are among those joining forces. The author argues that the advent of cloud technology should not be regarded as a further challenge to security but an opportunity to revitalize and improve a company’s defenses dramatically.
The objective of this work is to present a successful case study of deploying high power laser cladding in highly sour wells as protection from corrosion. High power laser cladding uses superalloy material and is welded to the pipe, creating a thin and strong film that adheres to the steel pipe. The technology is cost-effective and provides a long-term solution, extending the life of the pipes, casing, tubing, and other parts.
The method requires preconditioning the completion at the surface, applying a thin layer of superalloy (1 mm), and bonding it to the base material with a laser. The process will create a chemical bond between steel and the superalloy, which will result in a resistive layer facing the corrosive fluids. The technology was applied to carbon steel coupons (T-95 grade) and was cladded with three different superalloys Inconel-625, Inconel-825, and Hastelloy C-276. A bare coupon was used as a reference. The coupons were kept for three months downhole and later retrieved for analysis.
The technology was tested in extremely sour wells for three consecutive months. Well-A produces a high concentration of hydrogen sulfide (H2S) (35,000 ppm) while Well-B has a concentration of 14,000 ppm. A detailed analysis, including composition, X-ray fluorescence, environmental scanning electron microscope, and surface profiling on the coupons showed that the cladded samples have excellent resistance and no traces of corrosion on all the cladded coupons.
High power laser cladding is a cost-effective and promising technology that can extend the life of wells and minimize the frequency to replace the tubing due to corrosion issues. The cladded sample exhibits a more durable structure than the substrate materials. The superalloy thin layer protects from corrosion as it is a new pipe.
Targac, Gary (ConocoPhillips) | Gallo, Courtney (ConocoPhillips) | Smith, David (ConocoPhillips) | Huang, Chung-Kan (ConocoPhillips) | Autry, Sydney (ConocoPhillips) | Peirce, John (ConocoPhillips) | Baohong, Li (Daqing Xinwantong Science and Technology Development Co)
Waterflood conformance is a significant problem in the West Sak field of Alaska. Re-assembling Pre-Formed Particle Gels (RPPG) have been used to treat Void Space Conduits (VSC) and repair the "short-circuited" waterflood. These VSC’s are typically formed by sand producing wormholes. Several dozen VSC solutions have been implemented since 2006, including molten wax, cement blends, and pre-formed particle gels. To date, all the solutions have been faced with various limitations due to the low reservoir temperature and poor sand consolidation.
A good percentage of the pre-formed particle gel (PPG) solutions have been successful in sealing off VSCs, but often show limited longevity that can range from as little as several weeks to several years. An effort was undertaken to develop a product that would provide enhanced stability in the VSC and extend solution life beyond the current range. A cost-effective conformance solution was developed with increased mechanical strength through a re-crosslinking process known as RPPG. The goal of the RPPG solution is to provide a longer-term repair to a VSC and restore the primary water flood characteristics.
This paper will present the results of the seventeen RPPG solutions that have been pumped between 2017 and 2019 in the West Sak field on the North Slope of Alaska. RPPG treatments have shown a 23% improvement over traditional PPG treatments at the economic payout during the field trial. There have been some significant learnings through this time period. The focus of this paper will be to review the VSC problem understanding and the reason for the RPPG product development, detail the evolution of RPPG job design over time and provide results and operational knowledge from the field trial efforts.
The latest advancements in conformance engineering will be of interest to Reservoir and Production Engineers who are focused on supporting and optimizing conventional waterflooded assets, particularly when faced with conformance issues in an unconsolidated reservoir. In addition, the field results will be useful to those seeking to implement RPPG solutions in their area of operation.
Williston Basin oil-producing wells utilizing Electrical Submersible Pump (ESP) lift undergo severe challenges with respect to scale and corrosion due to high TDS brines (250,000 – 320,000 mg/L) and high shear and high temperature operating conditions (275ºF-325ºF at the ESP). Corrosion most commonly attacks the ESP, lower tubing, andannular space locations where the cable armor contacts the metal. Scale is primarily calcium carbonate due to ~20,000 mg/L of calcium in the brine and is commonly seen around the ESP where temperatures are highest. The severity of these conditions canlimit ESP run times to 3-4 months until failure.
Challenges for suitable protection from scale and corrosion include using specialty chemicals that provide temperature stability (325°F for the ESP environment and -40°F for winter temperatures at the surface), capillary qualification (the preferred delivery method), high TDS brine compatibility, and custom performance needs to address the various corrosion mechanisms. To this end, two strategies were developed combining uniquely qualified chemistries with specialized application. A new high temperature/high TDS scale/corrosion inhibitor was developed for delivery down the capillary
Using ESP run time as a metric and comparing treatments with a conventional scale/corrosion inhibitor combination, it was found that the new combination product provided a 73% increase in run time (230 v. 132 days). When the pre-conditioning corrosion inhibitor treatment was done in conjunction with the new combination product, the run time showed a 100% increase (264 v. 132 days). These findings are discussed in conjunction with improved practices for ESP management under severe corrosion and scale challenges. It is important to consider that any extension in ESP run time gained through mechanical or chemical means offers improved well production, lower operating expense, and improved profitability to the producer.