Model: Sampath1987/all-distilroberta-v1-offshore-energy
Author: Sampath1987
Pipeline: sentence-similarity
Library: sentence-transformers
Tags: sentence-transformers, safetensors, roberta, sentence-similarity, feature-extraction, dense, generated_from_trainer, dataset_size:89129, loss:MultipleNegativesRankingLoss, dataset:Sampath1987/offshore_energy, arxiv:1908.10084, arxiv:1705.00652, base_model:sentence-transformers/all-distilroberta-v1, base_model:finetune:sentence-transformers/all-distilroberta-v1, model-index, text-embeddings-inference, endpoints_compatible, region:us
Base models (finetune): id: sentence-transformers/all-distilroberta-v1
Card metadata: tags: sentence-transformers, sentence-similarity, feature-extraction, dense, generated_from_trainer, dataset_size:89129, loss:MultipleNegativesRankingLoss
base_model: sentence-transformers/all-distilroberta-v1
widget: source_sentence: How does vendor-specific data acquisition affect DTS profile interpretation?
sentences: Bridging data management gap by gathering all well integrity data in one unique data base. The aim of ADNOC Offshore in-house Well Integrity Data Management System (WIDMS) is to comply with the 3A rule: Accessibility of the data, Accuracy by performing regular quality check and Analysis. The analysis allows to maintain wells barriers robust, to ensure personnel safety and to quickly identify integrity issues to make qualified decisions about appropriate mitigations measures and avoid risk escalation. WIDMS has been developed in-house with inputs and collaboration of various stake holders. An enhancement list has been established selecting the most relevant features that will be added value to the system. Therefore, Automation for sub processes like thresholds calculations and Risk Assessment which gives input for Well Passports that contains all the required information to evaluate the well risks and implement the required mitigation measures.
End users are following a RACI Chart to keep WIDMS database on track and to ensure no data falls through the cracks as all the data workflow is defined through the different steps such as providing data, entering it in the system, informing relevant stakeholders and providing technical clarifications if needed. The result of data acquisition in WIDMS is that data flows across the entire organization, with defined access rights in line with ADNOC Offshore policies. This data is collected from various sources, is a robust data base, essential for evaluating and maintaining well integrity.
It is enhancing well barriers system management by allowing to have full overview of well's barriers performance. Moreover, it allows to have reliable and continuously available data such as annulus pressure data that is critical for well integrity assurance, to avoid the uncontrolled release of hydrocarbons to the atmosphere. Notifications have been implemented so alerts can be sent for engineers to inform about any abnormality and non-compliance. As technology evolves, using paper-based processes, excel spreadsheets, time-based equipment inspection and testing become less effective. Well diagnostics are expensive so utilizing well data analytics through this digital hub project will ease having detailed real time data and quick analysis for early detection of failures and anticipation and reduction of risk escalation., ##### 2.3.1 Site characterization - secondary seal  
Secondary seals might have a significant relevance in ensuring CO 2 containment, acting
as additional barrier to flow, although it is not clear if it is considered a requirement for
standards. Two documents show some contradiction:  
ISO 27914 [36] is silent on secondary seal as a requirement until section 5.4.3.2 that describes
its characterization. Moreover, if it is a requirement, characterization should include not
only geometry and lithology, but also integrity evaluation, which is not mentioned.  
ISO/TR 27915 [37] section 5.2.6 and Figure 2 state that the geological storage complex is
composed of the reservoirs where CO 2 is injected and the caprock (or seals); it then states
that additional geologic layers are outside complex., Geothermal energy is considered a reliable, sustainable and abundant source of energy with minimized environmental impact. The extracted geothermal energy may be utilized for direct heating, or electricity generation. The main challenge to access this energy is tremendous capital expenditures required for drilling and completion. Therefore, this work discusses and evaluates retrofitting abandoned petroleum wells to geothermal as a commonly proposed solution to the mentioned challenge.
There are many oil and gas wells globally which are not used for production, injection or other purposes. Well abandonment is commonly considered as an essential measure to ensure safety and integrity of these wells, bearing huge costs and concerns for the petroleum industry. By converting abandoned or non-activated oil and gas wells to geothermal wells, it is claimed to be possible to produce geothermal energy and generate power. As a crucial stage for the claim verification and evaluation of feasibility or efficiency of this conversion, it is important to be aware of the practical and simulation case studies.
Therefore, in this work, this work presents a comprehensive overview and analysis of 20 case studies published from different countries, followed by important downhole and surface parameters. As for the downhole characteristics, production scenarios either open-loop or closed-loop, optimization of open-loop systems, borehole heat exchangers with their different types and dimensions, and insulations are covered. Next, surface cycles including organic Rankine cycle (ORCs), selection of circulation fluids, flow rates, and working fluids are covered, followed by produced and net powers with evaluation of coefficient of performance (COP) and thermal efficiency. This investigation shows there is good potential for producing geothermal energy from abandoned and non-activated petroleum wells., source_sentence: Why must welding consumables be limited to specific classifications and manufacturers for EGW?
sentences: 8 API R ECOMMENDED P RACTICE 582  
**5.2.6 EGW**  
The use of EGW shall be limited by the following conditions:  
a) EGW shall be used only with filler materials specifically intended for the EGW process (ASME/AWS SFA/A5.26/
SFA/A5.26M),  
b) welding consumables shall be limited to the classification and the manufacturer’s trade name used in the PQR,  
c) only filler materials having classifications with specified minimum impact test requirements should be used.  
**5.2.7 SAW**  
**5.2.7.1** SAW procedures shall be requalified whenever the welding flux is changed from one manufacturer’s trade
name to another. Equivalence under ASME _BPVC_ Section II, Part C, or AWS filler metal specifications shall not be
considered adequate for substitution without requalification.  
COMMENTARY It is recognized that fluxes having the same classification can be very different in their
composition. However, nominal flux composition is not included in AWS or ASME specifications/codes, and flux
suppliers do not normally provide this information. Differences among fluxes of the same classification can result in
different and unanticipated weld properties when these fluxes are used interchangeably over the range of variables
typically stated in weld procedure specifications.  
**5.2.7.2** Manually held (semiautomatic) SAW is not permitted for welding pressure-containing parts, unless approved
by the purchaser.  
**5.2.7.3** A separate qualification is required for SAW welds in which any pass is greater than [1] / 2 in.  
**5.3 Single-sided Welded Joints**  
For single-sided welded joints where process side corrosion is a concern, welding processes using coatings or fluxes
shall not be used for root pass welding of austenitic stainless steels, non-ferrous alloys and nickel-base alloys unless
slag can be removed from the process side of root passes and the area inspected for slag removal.  
**5.4 Combining Welding Processes**  
Combining two or more welding processes that use alloy filler metals of different nominal compositions, other than A1
thro ~~ug~~ h A5, requires qualification as a combination procedure., Following multi-disciplinary reviews, an opportunity was identified to restore production and unlock incremental reserves from well X, a dual completion in two different reservoirs but subsequently deserted due to long term community crisis that led to over 25years of non-production with complete vandalization of well head and flowlines.
The method employed involved the strategic resolution of long-term crisis between two communities where well X is located, via a multi-disciplinary effort involving the operating company’s Community Relations, HSSE, Production Engineering, Operations Support and Portfolio Management functions. The installation of a retrofitted well head was done with first line and second line maintenance carried out. Wireline drifting and static bottom hole pressures were acquired for both strings using slickline equipment and a preliminary well test was conducted for both strings with production to a flowback tank.
The preliminary result for the long string (LS) indicated a high water cut (>80%), while the result from short string (SS) was in line with expectation (<57%). The test result from the short string informed the decision to construct a new flowline for restoring its production, while further subsurface evaluation is required for the long string (LS). The significance of the short string (SS) result is the unlocking of additional reserves ca. 1.0MMSTB from a reservoir with remaining oil in place estimated at ca. 18MMSTB, where the short string (SS) is the only drainage point currently completed on the reservoir.
This solution provides a cost effective and efficient way to increasing production and reserves at minimal expenditure leveraging on multi-disciplinary expertise, using existing infrastructures as well as resolving community crisis, where applicable., **Exploration & Production**  
**General Specification** Date: 10/2007  
**GS EP STR 301** Rev: 07  
successful practice of the process in previous similar jobs to the satisfaction of the
COMPANY.  
b) Only Extra Low Hydrogen processes (max. 5 ml H2/100 g) shall be used for welding and tack  
welding of Special and First Category members or materials having specified YS above
262 MPa (38,000 psi). The same requirement shall apply for any welding on castings and
forgings.  
c) For Second Category members and Non-Structural members, welding processes other than
Extra Low Hydrogen processes may be used, subject to prior approval by COMPANY, for
materials having specified YS up to 262 MPa together with thickness up to 12.70 mm
(0.500”).  
d) The number of different welding processes shall be minimized.  
e) Different welding consumables qualities (basic extra low, basic low,) in a same type of
consumables shall be avoided.  
**8.5 Welding consumables**  
**8.5.1 Selection of consumables**  
a) Consumables shall conform to ANSI/AWS D 1.1 code and shall have been approved by an
international recognized certification body (e.g. DNV, LLOYD’s, etc.).  
b) If classification of the structure is required, welding consumables shall conform to rules of the
Classification Society.  
c) Cellulosic electrodes are strictly forbidden for structural use  
d) Welds forming connections between steels of different grades of material shall develop the
minimum specified tensile properties of the lower steel grades being joined, unless otherwise
previously approved by the COMPANY.  
Welds forming connections between steels of different grades of material shall develop the
minimum specified notch impact properties at the lowest temperature of steel grades being
joined, unless otherwise previously approved by the COMPANY.  
e) For repair welding or multiple repairs, “extra low hydrogen” electrodes are required
(i.e. maximum specified hydrogen content of 5 ml per 100 gram of weld metal).  
f) For welding castings or forgings, “extra low hydrogen” electrodes are required (i.e. maximum
specified hydrogen content of 5 ml per 100 gram of weld metal)., source_sentence: What is the recommended use of blank samples in sampling procedures involving the trapping or precipitation of components?
sentences: elements. We do this by performing a similarity transformation on the matrix _k_ . The coordinate systems _x_ = { _x_ 1, _x_ 2 } and _y_ = { _y_ 1,, _y_ 2 } are related by the similarity transformation matrix  
_A_ such that  
_y_ = _Ax_ . ................................................................ (2.127)  
The two coordinate systems are shown in Fig. 2.6.
An angle ( _θ_ ) is associated with the transformation in Eq. 2.127 by writing the 2D coordinate transformation as  
_y_ 1  
_y_ 2  
_x_ 1  
_x_ 2  
=  
cos _θ_ sin _θ_  
−sin _θ_ cos _θ_  
. ........................................... (2.128)  
The coordinate systems _x_ = { _x_ 1, _x_ 2 } and _y_ = { _y_ 1,, _y_ 2 } are related by the counterclockwise rotation shown in Fig. 2.6. We have an aligned coordinate system _y_ = { _y_ 1,, _y_ 2 } with the
principal axes of the permeability tensor. The diagonal tensor in the coordinate system  
_y_ = { _y_ 1,, _y_ 2 } has the form  
_k_ ′=
(  
_k_ max 0  
0 _k_ _T_
) [, ......................................................... (2.129)]  
**Print** **Search** **Chapter 1** **Home** **Chapter 3** **Bookmarks** **Help**, **© 2010 COPYRIGHT MERCADO NEGRO, LAS PLAYITAS. MARACAIBO-EDO. ZULIA, VENEZUELA.**  
**PARA COMPRAR AL DETAL O AL MAYOR, ESTE Y OTROS PRODUCTOS, FAVOR PREGUNTAR POR EL GÖAJIRO BLANCO, EN EL MERCADO LAS PLAYITAS.**  
**ADVERTENCIA: "EL DERECHO DE AUTOR NO ES UNA FORMA DE PROPIEDAD SINO UN DERECHO CULTURAL. EXIGE TU DERECHO"**  
I-208 Petroleum Engineering Handbook—Vol. I  
**Fig. 4.10—Chromatogram showing broad OBM peak.**  
**Fig. 4.11—Chromatogram showing narrow OBM peak.**  
Special correction techniques are increasingly used within the oil industry, and because
these techniques vary between organizations and laboratories, sample selection should be done
only after considering which method to use. Many companies are forced to use oil-based
drilling muds to manage drilling costs in water-sensitive formations, and the added expense of
handling contaminated samples (and the risk associated with poorer-quality data) must be used
to evaluate the overall economic balance.  
For water samples, comparisons of duplicates also give a good indication of quality. Where
fluid concentration may be stabilizing (e.g., at the end of a cleanup), sequential samples should
be used to look for compositional trends and thus to help decide if representative fluid has
been sampled. For some sampling procedures involving trapping or precipitation of particular
components, it is highly recommended to use blank “samples,” which undergo exactly the
same treatment and storage as the actual sample and provide a reference measurement to assist
with the interpretation of laboratory measurements. More details are available in API _RP 45._ [10]  
**Print** **Search** **Chapter 3** **Home** **Chapter 5** **Bookmarks** **Help**, the ideal time to take samples? (6) Will on-site analyses be required? (7) Who will perform
sampling and analysis duties?
Fluid-sampling operations are often left to service-company personnel, but because significant variation in levels of competence exists within the industry and within service companies
themselves, it is recommended either to use specialist laboratory personnel or to supervise the
service-company operations closely.
General guidelines for choosing reservoir-fluid-sampling methods and sample quantities required are summarized in **Table 4.2.** Regardless of the actual volumes mentioned, you should
collect at least two separate samples of each fluid, referred to as duplicate or replicate samples.
This reduces the chance of losing information if one of the samples leaks or is accidentally
damaged during laboratory operations, and it allows a comparison between the samples as part
of the quality-control procedures.
Surface-separator sampling is the most common technique, but the reservoir-fluid sample
recombined in the laboratory is subject to errors in the measured GOR and any imprecision in
the laboratory recombination procedure. Downhole samples (or wellhead samples) are not affected by such inaccuracies but require the fluid to be in monophasic condition when sampled;
this can be confirmed definitively only afterward in the laboratory. Also, there is general reluctance to attempt downhole sampling in gas/condensate reservoirs because many are saturated,
and the phases are likely to segregate in the wellbore. The ideal situation for a laboratory is to
receive both surface and downhole samples because a choice is then available, and a good idea
can be obtained of how representative the resulting fluid is.
In certain circumstances, it can be good practice to collect “backup” fluid samples at the
earliest opportunity during a production test, even if a well has not cleaned up properly. If the
test has to be aborted for some reason [well bridging, unexpected levels of hydrogen sulfide
(H 2 S), etc.], the backup samples may be of great value, even if they are not 100% representative. If the test is completed successfully, the backup samples can be discarded to avoid the
cost of unnecessary shipment and testing.
If sampling is part of a long-term monitoring program, such as those required by government authorities or those forming part of custody-transfer contracts, the methods defined in the
appropriate documentation or contracts must be followed as closely as possible, even if this, source_sentence: What is the significance of implementing a centralized, web-based integrated surveillance tool for production optimization?
sentences: P RESSURE                - RELIEVING AND D EPRESSURING S YSTEMS 141  
**5.7.11.2.3 Flare Gas Characteristics**  
Flare gases can have widely varying compositions that shall be evaluated during specification of recovery systems.
The potential for materials that are not compatible with the flare gas treating systems or ultimate destinations shall be
determined. For example, relief streams containing acid gases typically are routed directly to the flare, thereby
bypassing the recovery system. Highly inert streams can also be incompatible with recovery systems.  
**5.7.11.3 Design Considerations**  
**5.7.11.3.1 Sizing**  
Figure 13 shows a conceptual design for a flare gas recovery system. Typically, the system consists of one or more
reciprocating compressors whose suction is directly connected to the flare header. The compressed gas is usually
routed to some type of treating system appropriate for the gas composition, then to fuel gas or processing systems.  
3  
**Key**
1 compressor load control
2 flare gas treating
3 from process unit flare knockout drums  
4 flare header  
5 flare knockout drum (if used)  
6 water seal  
7 flare  
a Compressor shutdown.  
**Figure 13—Typical Flare Gas Recovery System**  
Copyright American Petroleum Institute
Provided by IHS under license with API Licensee=Petrofac International Ltd/5954785001, User=McNicol, William
No reproduction or networking permitted without license from IHS Not for Resale, 01/29/2014 03:10:03 MST, Inorganic scale precipitation and deposition in oil and gas wells can cause significant production loss, which results in additional operational expenditure (OPEX) and health safety and environmental (HSE) risks. Scale management requires a detailed understanding of production rates, hydrocarbon and produced water compositions as well as reservoir conditions. Accurate real-time analysis of produced water compositions can immediately identifiy scaling risks in a production well and can lead to significantly reduced production loss, optimized chemical dosages, and fewer workovers, consequently lowering OPEX and mitigating HSE risk. This paper introduces development of a device capable of measuring the most critical parameters associated with inorganic scale in flowing produced water including pH, alkalinity, strontium, barium, sulfate, total hardness, total dissolve solids (TDS) and others.
In order to measure these water properties with the device, different methods were tested, but eventually, a combination of spectrophotometric and other methods were determined effective. One of the challenges of using spectrophotometric methods is the reagent stability over time. Hence, customized reagents were prepared for this application and the stability of these reagents was tested over time. Specific calibration methods were designed in order to extend the usage of the reagents.
Static measurements were initially performed and the results showed precise measurements of all the parameters. Results from dynamic tests utilizing real time flow and static test were in agreement and the accuracy was confirmed by traditional methods. Once the device prototype was built in our laboratories, production fluids were used to test the complete device. This device can be placed at various attachment points from the wellhead to the separator. This automated device is capable of collecting a discrete production fluid sample, separating produced water from the bulk phase and measuring various properties of produced water. These properties are reported electronically and used as part of a combined real time scale risk prevention system. In addition, this device measures parameters while maintaining wellhead pressure and temperature in order to eliminate the potentials errors in measurements, for instance pH of water changes due to degassing and precipitation as a result of changes in pressure and temperature.
A field trial is planned to test the device under full flowing conditions. This will be the first automated real-time produced water composition monitoring device with high measurement accuracy while maintaining pressure and temperature of samples, which can be attached at various points from wellhead to separator. This can be beneficial to identify the scaling risk in production wells before severe scaling occurs. The device is designed to enhance reliability of water properties measurements, provide real-time measurements, and reduce downtime and costs associated with scale problems and sampling., In 2009, the Kuwait Integrated Digital Field (KwIDF) project was established in the Sabriyah field in north Kuwait to boost production and reserves (Al-Jasmi et al. 2014). The goal was to help realize the vision of sustained oil production in Kuwait of four million barrels of oil equivalent per day (BOE/D) by 2030 (Goel et al. 2013). The project involved the creation of 11 integrated, automated workflows, and a real-time collaborative environment to help optimize production, reduce downtime, and improve reservoir management:
Key performance monitoring—calculates and displays key parameters to monitor and assess asset performance at the field and well levels (Al-Jasmi et al. 2013).
Well performance evaluation (WPE)—allows users to model and evaluate any well in real time, from completion face to wellhead (Cullick et al. 2013).
Smart production surveillance (SPS)—helps enable users to control production and make surveillance decisions in real time (Villamizar et al. 2013).
Production loss—an advance workflow for users to compare current oil production to pre-established allowable rates (Villamizar et al. 2013).
Electric submersible pump (ESP) diagnostic and optimization—helps enable users to interactively monitor and optimize ESP operated well operations (Velasquez et al. 2013).
Production allocation—integrates the allocation process within the KwIDF environment, increases the frequency of the allocation cycle, and improves the accuracy of allocated volumes (Al-Jasmi et al. 2013).
Gas lift (GL) diagnostic and optimization—uses a smart real-time control that provided proactive recommendations for GL systems optimization (Al-Jasmi et al. 2013).
Reporting and distribution—displays system generated alarms from all KwIDF workflows, generates tickets, and reports ticket status (Al-Jasmi et al. 2013).
Simulation model update and ranking—an automated workflow for reservoir history matching (Carvajal et al. 2013).
Reservoir visualization and analysis, and subsurface waterflood optimizer—helps enable the monitoring of subsurface health during the waterflooding process, and provides predictive reservoir optimization analysis and actions (Ranjan et al. 2013).
By 2012, KwIDF had been deployed on 49 wells, representing a pilot that served as a proof of concept. By 2013, cumulative production gains of 756,000 barrels of oil were reported (Singh et al. 2013). While the gains were impressive, and management wanted to expand KwIDF, it was recognized that full deployment would pose significant challenges and, without a set of necessary changes, the value of KwIDF would not be realized.
The key challenge facing management was to identify the appropriate operating model to deliver on the KwIDF vision and scale the program to accommodate future expansion across the rest of the organization. A transition and deployment assessment team was established by management to address this challenge.
The transition and deployment assessment project produced a recommended operating model, a transition road map, change management strategy, risk and mitigation plan, and project charters to assist the program team and steering group in the deployment of KwIDF across the rest of North Kuwait., source_sentence: What role did anti-collision analysis play in the drilling of the dual lateral well?
sentences: This paper aims to analyze the impact of appraising and developing marginal fields with multiple stacked reservoirs which is quite challenging in terms of techno commercial value. The development of such marginal reservoirs using conventional single horizontal wells drilling and completion is uneconomical. Therefore, it was necessary to engineer a solution that can enhance the commercial value of the project by reducing CAPEX and OPEX. This paper will present the first comprehensive business case, where multiple stacked reservoirs with marginal reserves were studied to produce independently using multilateral completions, granting full accessibility of the laterals while achieving production monitoring and reservoir surveillance., This paper is a comprehensive analytic driven study on the use and sizing of membrane filters to improve the injected water quality for maintaining injectivity in tight carbonate reservoirs. Out of the different mechanisms of formation damage, the pore plugging with the migration of particles within the injectant fluids by bridging at the pore throat junctions and/or by pore filling can lead to the buildup of an internal filter cake away from the wellbore that limits the well’s injectivity and can affect the vertical and lateral sweep.
This type of formation damage is very difficult to treat with any kind of stimulation and the impact will be manifested especially in tight formations with interbedded stylolites layers with a total range of permeabilities from 2 to less than 1 milli-Darcy and a median pore throat size ranging from 2.5 to 0.3 micron meters. The study comprises several parts starting with a geological analysis that was conducted to identify areas and layers most prone to formation pore plugging by analyzing thin-sections and MICP data. Second, in the lack of core flood tests, a reservoir and well study analyzed existing water injectors situated in similar or slightly higher quality rock areas through the analysis of injectivity index behavior to estimate the impact of damage and the expected injector’s half-life.
As a result, through the application of an analytical mathematical model for defining deep bed filtration parameter, a correlation was established based on average injected particle size and reservoir rock quality to aid in selecting the proper water injection filter size. In order to confirm that, a dedicated injectivity test in a horizontal well utilizing membrane filters was carried out to assess eventual formation damage and the filters efficiency by conducting a series of multiple pressure fall-off tests coupled with injection profile logging to monitor any induced damage within the wellbore region.
Finally, the operational aspects and the integration within field development plans were addressed, especially with the recommended well placement and completion. This culminated in a field development strategy for formation damage mitigation in tight carbonate reservoirs during production and injection phase that can be used in other similar fields., The most common challenge in horizontal drilling is depth uncertainty which can be due to poor seismic data or interpretation. It is arguable that a successful landing of the wellbore in the reservoir optimally and within the desired zone is the most challenging in most geosteering operation. The presence of fluid contacts such as oil-water-contact (OWC) and gas-oil-contact (GOC) complicates the whole drilling process, most especially if these fluid contacts are not well defined or known. Additionally, the ability to map the boundaries of the reservoir as the BHA drills the lateral section is an added advantage to remaining within the desired reservoir section.
The success of any reservoir navigation service where seismic uncertainty at the reservoir top is high will rely largely on how effective the geosteering system is and how the geosteering engineer is able to react promptly to changes while landing the well in the reservoir and drilling the lateral section with without exiting the reservoir.
Reservoir Navigation Service (RNS) provides the means for the drilling near horizontal or horizontal wells for the purpose of increasing hydrocarbon extraction from the earth's subsurface. This involves the use of a pre-defined bottom hole assembly (BHA) with inbuilt downhole logging while drilling (LWD) and measurement while drilling (MWD) sensors. The measurements from these downhole sensors are uplinked to the surface of the wellbore where they are converted to meaningful petrophysical data. The goal is to use the downhole petrophysical data such as gamma ray, propagation resistivity and so on, to update an existing pre-well geological model of a section of the earth in such a way that the final result depicts the true model picture of the earth subsurface.
This paper focuses on using well CBH-44L to showcase how the use of real-time distance-to-boundary (D2B) measurement from a deep reading azimuthal propagation resistivity tool is use to correct for depth uncertainty in seismic, thereby, improving the chance of successfully landing and drilling a horizontal well.
datasets: Sampath1987/offshore_energy
pipeline_tag: sentence-similarity
library_name: sentence-transformers
metrics: cosine_accuracy
model-index: name: SentenceTransformer based on sentence-transformers/all-distilroberta-v1
results: task: type: triplet
name: Triplet
dataset: name: ai job validation
type: ai-job-validation
metrics: type: cosine_accuracy
value: 0.68781977891922
name: Cosine Accuracy
verified: no
Likes: 0 | All-time downloads: 53
Created: 2025-09-11 14:55:10