Completion Technology Resources (Norway)

The Vecchietti procedure is a staged procedure that, through use of an acrylic olive, allows for expedited traction and dilation to create a neovagina in patients with congenital vaginal agenesis. Although the steps are fairly standardized for the laparoscopic Vecchietti procedure, we have appreciated specific nuances in technique that have optimized our surgical approach and efficiency. We present a case of congenital vaginal agenesis in a genetically female patient who completed neovaginal creation using the laparoscopic Vecchietti technique. During this case, we review each step of the procedure and offer technical strategies to enhance efficiency and effectiveness in the operating room. We also describe these specific preoperative, intraoperative, and postoperative considerations in a video. This optimized Vecchietti procedure, or traction vaginoplasty, is an excellent option for neovagina creation in those patients with vaginal agenesis. With the use of our techniques, we have had successful cosmetic and functional outcomes.

IntroductionMentor Mothers (MM) provide peer support to pregnant and postpartum women living with HIV (PPWH) and their infants with perinatal HIV exposure (IPE) throughout the cascade of prevention of vertical transmission (PVT) services. MM were implemented in Zambézia Province, Mozambique starting in August 2017. This evaluation aimed to determine the effect of MM on PVT outcomes.MethodsA retrospective interrupted time series analysis was done using routinely collected aggregate data from 85 public health facilities providing HIV services in nine districts of Zambézia. All PPWH (and their IPE) who initiated antiretroviral therapy (ART) from August 2016 through April 2019 were included. Outcomes included the proportion per month per district of: PPWH retained in care 12 months after ART initiation, PPWH with viral suppression and IPE with HIV DNA PCR test positivity by 9 months of age. The effect of MM on outcomes was assessed using logistic regression.ResultsThe odds of 12‐month retention increased 1.5% per month in the pre‐MM period, compared to a monthly increase of 7.6% with‐MM (35–61% pre‐MM, 56–72% with‐MM; p < 0.001). The odds of being virally suppressed decreased by 0.9% per month in the pre‐MM period, compared to a monthly increase of 3.9% with‐MM (49–85% pre‐MM, 59–80% with‐MM; p < 0.001). The odds of DNA PCR positivity by 9 months of age decreased 8.9% per month in the pre‐MM period, compared to a monthly decrease of 0.4% with‐MM (0–14% pre‐MM, 4–10% with‐MM; p < 0.001). The odds of DNA PCR uptake (the proportion of IPE who received DNA PCR testing) by 9 months of age were significantly higher in the with‐MM period compared to the pre‐MM period (48–100% pre‐MM, 87–100% with‐MM; p < 0.001).ConclusionsMM services were associated with improved retention in PVT services and higher viral suppression rates among PPWH. While there was ongoing but diminishing improvement in DNA PCR positivity rates among IPE following MM implementation, this might be explained by increased uptake of HIV testing among high‐risk IPE who were previously not getting tested. Additional efforts are needed to further optimize PVT outcomes, and MM should be one part of a comprehensive strategy to address this critical need.

Abstract Novoportovskoye Field is classified as large and is characterized by complex geological structure, reservoir development is complicated by bottom water and gas caps. The field is developed by horizontal wells with a horizontal section length of up to 2,000 m and various completion methods: Assemblies with extended screen sections isolated by packersAssemblies with sliding ball-activated hydraulic fracturing collarsInternal-flush assemblies with hydraulic fracturing collars (30pcs) activated by a special CT-conveyed device. To estimate the efficiency of multi-stage hydraulic fracturing in horizontal wells, a module has been developed that allows estimating the effect of the primary and repeated fracturing. The module takes into account the increase in the number of frac stages, fracture half-length and width, it allows to estimate the risks of clay barriers breakthrough, evaluate reservoir properties, and select the stimulation option. To select wells for Hz sidetracking and infill drilling, an algorithm for identifying undeveloped reservoir sections was applied to evaluate the efficiency of well interventions and assess the risks in each zone. In the conditions of oil rims, to increase the efficiency of reservoir development using horizontal wells with screen completions, it is recommended to use casing packers in a liner assembly that divide the horizontal borehole into isolated sections. This solution will allow to perform targeted isolation / stimulation of a certain horizontal interval in the process of well operation in case of a decrease in productivity and water/gas breakthrough. As a result, the cost-effective life of a well will be extended and the oil recovery factor of the field will be increased. A twin-packer technology for a targeted stimulation of a certain interval in a horizontal wellbore was tested and successfully implemented by Gazpromneft-Yamal.

Abstract Today's conventional sand control screens, such as slotted liner, wire wrap, and premium mesh (both fusion-bonded or "soft-sintered"), retain sand via arrays of single-sized gaps. Although open flow area and mechanical strength differ among such screens, the sand retention mechanism is virtually the same—2 dimensional and gap-based—and performance is sensitive to the particle size distribution (PSD), which is not always well defined or constant along a horizontal wellbore. A very different sand control screen was developed that consists of a ~6 mm thick bed of highly compressed stainless steel wool and is protected by a perforated jacket with about 40% open flow area. The wool fibers criss-cross randomly to create a wide distribution of angular (rhombohedral) pores designed to retain a wide range of PSDs without plugging. Furthermore, this unique, three dimensional filter allows more "harmless fines" to pass, especially during startup, thereby creating an enhanced permeability layer of sand against the screen. About 1 million feet of this screen has been installed to date (mostly in producers but also in injectors) in a wide range of applications—SAGD, cyclic steam, steam drive, conventional heavy and light oil, gas, gas hydrates, and water producers/injectors—with a remarkably high success rate. Due to its high flow capacity and strength, it has become popular for pump protection and for re-completions inside failed screens. Furthermore, this screen has been successfully replacing gravel packing in certain fields due to its enhanced performance characteristics and lower cost. It has proven attractive for standalone completions in long horizontals where the PSD is either poorly defined or varies significantly from heel to toe. This paper presents the highlights of recent laboratory testing and field experience that demonstrate the screen's wide range of application, robust characteristics, and unique ability to enhance productivity and handle a wide range of sands with one "gauge". The screen's limitations are also presented. With today's emphasis on standalone screen (SAS) completions, cost reduction and long horizontals, a presentation of this screen's properties and recent performance is very timely. Furthermore, this screen has recently been combined with inflow control devices (ICDs) to equalize toe-to-heel flux in order to prevent/delay water/gas coning and also minimize watercut if/when water eventually migrates to the wellbore.

Abstract A novel timer activated sandface valve was developed that has significant impact on wellbore productivity by enabling improved wellbore clean up, particularly in high angle and open hole completions. This technology has been field trialled and proven in three wells in a North Sea field. The tool was developed from concept to installation in less than nine months including detailed engineering review and assurance. Negative impact to productivity due to inefficient wellbore clean up of high angle completions is a common situation for production wells. The current solution can be complex completion architecture or extensive clean up procedures that are both expensive and difficult to implement. The consequence of a poor clean up can be loss in well productivity, access to reserves or a requirement to sidetrack the well. Poor clean up was observed in several wells in a North Sea field. The wells exhibited high skin and no flow from the toe sections of the well due to the dominance of high productive intervals subject to high drawdown at the heel of the well. The timer activated sand face valve was developed with the key objective to deliver sequential clean up from the toe of the reservoir section without intervention or incremental rig time. The valves also deliver the functionality of a sliding side door for future water shut-off capability along the well bore. The paper will present an overview of the technical challenge, detail development of the tool and processes used for assurance and include results of the field trial. The valve development combines a field proven timer activation mechanism with conventional sliding sleeve technology. The tool was developed without incremental resource and cost often required for product development utilising specifically designed lean technical assurance tools and failure mode and effects analysis processes. The result is a successfully field proven completion tool that is the basis for a new completion technique that has application in high angle wells in all oilfield applications.