Model: Sampath1987/mpnet-energy
Author: Sampath1987
Pipeline: sentence-similarity
Library: sentence-transformers
Tags: sentence-transformers, safetensors, mpnet, sentence-similarity, feature-extraction, dense, generated_from_trainer, dataset_size:53913, loss:MultipleNegativesRankingLoss, dataset:Sampath1987/offshore_energy_v1, arxiv:1908.10084, arxiv:1705.00652, base_model:sentence-transformers/all-mpnet-base-v2, base_model:finetune:sentence-transformers/all-mpnet-base-v2, model-index, endpoints_compatible, region:us
Base models (finetune): id: sentence-transformers/all-mpnet-base-v2
Card metadata: tags: sentence-transformers, sentence-similarity, feature-extraction, dense, generated_from_trainer, dataset_size:53913, loss:MultipleNegativesRankingLoss
base_model: sentence-transformers/all-mpnet-base-v2
widget: source_sentence: How does the monitoring system for well integrity function after CO2 injection?
sentences: Drilling is a complex process and delivering a successful well requires identifying proper technologies and utilizing them efficiently to save time & cost. Today in Oil & Gas industry there is a huge focus on digital technologies to improve Drilling Process efficiency and PDO decided to implement an innovative approach of process optimization by implementing a unique project "electronically Delivering the Limit (eDtL)".
The overall approach with eDtL project was to implement a platform which can provide Drilling Operations team the technical limit for all Drilling Activities, which is the theoretical minimum time required to perform an activity, based on available knowledge and technology.
eDtL system utilizes rig sensors data transmitted in Real-Time from Drilling Rigs to automatically detect the Rig Activity and focus on identifying the areas of Drilling Performance Improvements and minimizing redundant tasks for rig and office teams. The identified opportunities are communicated with rig team for implementation and the performance is tracked again to highlight the improvements.
eDtL system also provides capability for continuous improvement of organizational processes by introducing automation of redundant tasks. One of such improvement was partial automation of Daily Drilling Report which was historically manually recorded by rig team daily., ADNOC has embarked on a major Carbon Capture and Storage (CCS) project where large quantities of CO2 are injected into deep saline aquifers for permanent storage instead of releasing into the atmosphere.
An advanced chemical tracer technology was deployed in the first CCS project in the UAE for continuous CO2 monitoring to ensure permanent and safe CO2 storage. In case of containment breach, the chemical tracer technology can confirm the leakage and identify its source.
After CO2 injection for permanent storage, any containment breaching would be detected in the shallow soil monitoring borehole. Few soil monitoring boreholes were excavated across the field in which Capillary Adsorption Tubes (CAT) were inserted for some time and replaced by another according to the sampling frequency plan. The tube is sent to the lab for CO2 leak detection and reporting. The high detection resolution is in the order of 0.1 parts per trillion (ppt). This has a positive impact on the system economics because smaller quantities of chemical tracer material are required.
The tracer injection monitoring system is ongoing in the first CO2 storage area of Abu Dhabi. The monitoring includes soil monitoring which are shallow boreholes. The soil monitoring boreholes were excavated close to the CO2 injection well to ensure that there are no well integrity issues developed due to thermal effects by CO2 injection. The soil monitoring boreholes to be verified by surface gas CO2 monitors. Soil monitors were located around the radial storage area, to detect CO2 leakage and to understand CO2 migration to the soil through the cap rock (in case of leakage). The monitoring system for caprock and well integrity will provide: Surface soil monitoring for cap rock integrity, integrity confirmation for legacy wells, integrity confirmation of injection well in the post-injection monitoring period, leakage quantification, leakage origin if multiple injectors. The monitoring system can continue for up to 30 years of the operational period as well as the full post-injection monitoring, measurement and verification horizon.
This paper presents a description of a sophisticated CO2 monitoring technology that is being deployed in UAE's first CCS project. CO2 tracer technology is considered as one of the most accurate methods to detect CO2 leakage at surface. Its high-detection resolution allows early leakage identification and early mitigation action. In addition, it proves to be relatively low cost, operationally easy to execute, and requires a small operational footprint., Carbon Capture and Storage, as a solution to mitigate the increase in greenhouse gases emissions in the atmosphere, is still bringing intensive worldwide R&D activities. In particular, significant acceleration of in situ CCS experiments supports technical developments as well as acceptability of this technology. Among the major risks identified to this technology, wells are often considered to be the weakest spots with respect to CO2 confinement in the geological reservoir. Therefore, long-term well integrity performance assessment is one of the critical steps that must be addressed before large scale CCS technology deployment is accepted as a safe solution to reduce CO2 emissions.
A risk-based methodology associated with well integrity is proposed within CO2 geological storage. The main objectives of this approach are to identify and quantify risks associated with CO2 leakages along wells over time (from tens to thousands of years), to evaluate risks and to propose relevant actions to reduce unacceptable risks. The methodological framework emphasized the use of the risk concept as a relevant criterion to (i) evaluate the overall performance of well confinement with respect to different stakes, (ii) include different levels of uncertainty associated to the studied system, and (iii) provide a reliable decision making support. For the quantification of risk, a coupled CO2 flow model (gas flow and degradation processes) was used to identify possible leakage pathways along the wellbore and quantify possible CO2 leakage towards sensitive targets (surface, fresh water, any aquifers…) for different scenarios. This approach offers an operational response to some of the challenges inherent to well integrity management over well lifecycle.
This paper focuses on the application of the methodology to a synthetic case based on an existing well. The practical outcomes and the added values will be presented: (i) an objective and structured process, (ii) scenarios identification and quantification of CO2 migration along the wellbore for each scenario, (iii) risk mapping, (iv) and operational action plans for risk treatment of well integrity., source_sentence: How did the detailed pre-survey planning impact the success of the offshore seismic acquisition campaign?
sentences: We showcase an innovative campaigning and business-focused approach to reservoir monitoring of multiple fields using 4D (time-lapse) seismic. Benefits obtained in terms of cost, speed and the quality of insights gained are discussed, in comparison with a piecemeal approach. Challenges and lessons learned are described, with a view to this approach becoming more widely adopted and allowing 4D monitoring to be extended to smaller or more marginal fields.
An offshore seismic acquisition campaign was planned and successfully executed for a sequence of four 4D monitor surveys for fields located within 250 km of each other on the greater Northwest Shelf of Australia. The four monitors were acquired in H1 2020 comprising (in this order): Pluto Gas Field M2 (second monitor), Brunello Gas Field M1 (first monitor), Laverda Oil Field M1 and Cimatti Oil Field M1.
Cost savings expected from campaigning were realised, despite three cyclones during operations, with success largely attributed to detailed pre-survey planning. Also important were the choice of vessel and planning for operational flexibility. The baseline surveys were diverse and required careful planning to achieve repeatability between vintages over each field, and to optimise the acquisition sequence – minimising time required to reconfigure the streamer spreads between surveys. The Cimatti baseline survey was acquired using a dual-vessel operation; modelling, combined with now-standard steerable streamers, showed a single-vessel monitor survey was feasible. These optimisations provided cost savings incremental to the principal economy of sharing vessel mobilisation costs across the whole campaign.
Both processing and evaluation (ongoing at the time of writing) are essentially separate per field, but follow a consistent approach. Processing is carried out by more than one contractor to debottleneck this phase, with products, including intermediate quality control (QC) volumes, delivered as pre-stack depth migrations. While full evaluation of the monitor surveys to static and dynamic reservoir model updates will continue beyond 2020, key initial reservoir insights are expected to emerge within days of processing completion, with some even earlier from QC volumes. Furthermore, concurrent 4D evaluations are expected to result in fruitful exchanges of ideas and technologies between fields., Advances in seismic acquisition, processing, computing hardware and theory continue to enhance seismic-image quality. However, an investment decision on seismic projects should be based not only technical criteria but a quantifiable expected value above all currently available field data including well information. This presentation will include a case history of a major carbonate oil field demonstrating how this value was estimated before a major reprocessing project and how this value is being achieved.
This field contains over 1000 wellbore penetrations. A 3D seismic survey was acquired over the field during 2001–2002, but the reservoir development team believed that these data to date had added limited value. The motivation for evaluating the potential for further investment in seismic data was a multi-billion-dollar field-redevelopment plan.
The Value of Information (VOI) exercise to justify a seismic project began with an evaluation of technical issues that limited the use of existing seismic data. Through a targeted fast track reprocessing effort it was determined that the existing survey had been designed and acquired adequately, and that the deficiencies in the dataset at the reservoir level are primarily caused by near-surface and overburden effects. The first-order impact is that mapped seismic surfaces exhibit a "roughness" primarily from the overlying "non-geologic" noise. There was concern that many subtle faults interpreted at the reservoir level could be "non-geologic" artifacts which resulted in reluctance to incorporate these into the reservoir model. Amplitude balancing issues in the original data precluded quantitative assessments such as porosity prediction. The targeted reprocessing also verified that existing algorithms and traditional workflows alone were insufficient to resolve the technical issues.
Working with the reservoir development team the key business drivers for reprocessing were identified as follows:
Increase individual well productivity and recovery
Image and define new opportunities in current poor-data areas
Save on well cost by preventing re-drills
Improve overall field development plan
Specific expected value metrics and risks were assigned to the above objectives and a VOI assessment was completed. It was estimated that successfully achieving the above business objectives would result in a potential value at least 15 times the cost of the reprocessing. This resulted in management approval of the full field reprocessing.
Following completion of the seismic reprocessing, the project team objectively assessed whether the technical criteria had been achieved and if the business criteria will be achieved. In both cases the team determined that value metrics will be met. The reprocessing has impacted drill-wells as well as field development planning. In addition, the reprocessed seismic data will produce additional potential value as a result of opportunities not recognized at the start of the project., Sabiriyah Mauddud is a giant reservoir in NK under active water flood with about 200 producers and 32 injectors. The reservoir has no aquifer or insignificant energy support and had been on production since 1960s. Water flood started in the year 1997, initially with a pilot and later on expanded to the full field in a phased manner. Initial development was on pattern flood concept with all vertical injectors & producers which has now been replaced with Produce High-Inject Low (PHIL) concept using horizontal wells. In light of the significance of this reservoir for Kuwait's production, all efforts are made to optimize the performance of this reservoir. To achieve this objective, Pressure monitoring & performance analysis is considered to be the backbone of all production as well as injection activities.
This paper presents the methodology conceived and implemented to assess the reservoir pressure performance and estimate the current reservoir pressure in different segments/ blocks in an innovative way so as to maximize the value of "Water flooding" in North Kuwait area along with the meeting of production aspirations using ESP as artificial lift system in an optimized manner. Except the RFT data in newly drilled wells, the availability of pressure data was limited during recent past, making it necessary to integrate all the available information so as to build a powerful tool to be used for water flood monitoring. All available information – Repeat Formation Tester "RFT", Static Bottom Hole Pressure "SBHP" and Pump intake pressure "PIP" under dynamic and static conditions, were collected & analyzed. An initial study related to compartmentalization showed two main areas, north and south, based on comprehensive analysis of all the pressure points. The analysis also helped for identifying areas with good vertical connectivity and understanding segments with vertical barriers matching with the geological description. In order to have the latest pressure mapping, data were combined to have an integrated imagery of the pressure distribution across the reservoir. During the exercise, "Gaps" were identified which were filled in by the intake pressure live data as well as shut in data to have a meaningful mimic of the reservoir pressure to help the ongoing production as well as injection activities.
Based on the innovative approach as above, surveillance plan has been made to further enhance the quality of the mapping. Several maps such as opportunity map; PVT properties map; layer wise pressure maps etc. have been generated for ready-to-use information to facilitate daily operations.
The objective of the paper is to share the innovative, simple, smart and very useful approach adopted by North Kuwait to manage the giant Mauddud. This paper presents the methodology conceived and implemented to assess the reservoir pressure performance and estimate the current reservoir pressure in difference segments/ blocks in an innovative way so as to maximize the value of "Water flooding" in North Kuwait area along with the meeting the production aspirations using ESP as artificial lift system in an optimized manner., source_sentence: What are the primary recovery techniques used in oil and gas extraction?
sentences: The extraction of oil and gas involves various techniques to enhance recovery rates. Primary recovery relies on the natural pressure of the reservoir, while secondary recovery techniques such as water flooding and gas injection are employed to increase output after primary methods become inefficient. Tertiary recovery methods, also known as enhanced oil recovery (EOR), use thermal, gas, or chemical injection to further improve extraction rates. Each method comes with its own cost implications and efficiency rates, which can significantly affect the overall economics of an oilfield development project., In this paper one of the areas of conflicts observed with the performance of horizontal wells standoff with respect to development of thin oil rim reservoirs is examined.
In a technical paper as part of the critical review of literature on the exploitation of thin oil rim reservoirs with large gas cap and aquifer, this author had highlighted the problem. As part of sensitives in horizontal well standoff, Cosmos and Fatoke (2004) tested three positions; one-third, centre and two-third positions from the GOC in a Niger Delta field. They concluded that the landing closest to the GOC (one-third position) yielded lowest Oil compared to the centre and two-third positions. Surprisingly the work done by Sai Garimella et al (2011) in a 60ft Ghariff & Al Khlata shallow marine low permeability sandstone reservoirs in a field in Oman showed a different result with the one-third position indicating an optimum recovery from a horizontal well. Interestingly both authors positions on the performance had support from other authors.
This study used a 3D reservoir model, investigated different horizontal well standoff performances and applied permeability reduction to simulate different reservoir quality. The objective was to see if the reservoir quality was a factor in the different horizontal well standoff performance seen from different regions of the world while noting their different depositional environments. Results from the investigation is presented in this paper and shows a different trend from both authors mentioned above., The oil extraction process typically involves drilling a well into the earth's crust where oil deposits are located. The well is often lined with casing to prevent collapse and water intrusion. Once the well is drilled, various techniques such as primary recovery, secondary recovery, and tertiary recovery can be employed. Primary recovery uses natural reservoir pressure to extract oil, while secondary recovery employs water or gas injection to maintain pressure. Tertiary recovery, also known as enhanced oil recovery, uses techniques like thermal injection or chemicals to further reduce the viscosity of oil and increase extraction rates. Each of these methods has distinct implications on the yield and economic viability of oil extraction operations., source_sentence: What advantages do helicopters have over fixed-wing aircraft for leak detection surveys?
sentences: The reservoir characteristics such as porosity and permeability are crucial for evaluating the potential of oil and gas fields. Porosity refers to the void spaces within rocks that can hold hydrocarbons, while permeability measures how easily fluids can flow through rock formations. These two properties significantly influence the extraction methods used and the overall productivity of a reservoir. Enhancing permeability through hydraulic fracturing has become a common technique in unconventional resource extraction, allowing for more efficient recovery of oil and gas from low-permeability reservoirs., BP gas production operations in North America manages over 15,000 miles of onshore pipelines that make up our vast, complex, and aging gas gathering networks. Surveying these for leaks presents a huge resource challenge using current ground based technology and, in turn, impacts the assurance of the safety and integrity of these operations.
The Exploration and Production Technology Group evaluated new leak detection technologies using laser, thermal imaging camera and a high speed gas sampling detector that were deployed on aircraft and used global positioning systems coordinates to survey gas gathering pipelines. Field trials on gas gathering systems in the North Texas, Anadarko asset showed that the laser and gas sampling based leak detection systems were the most accurate, but the video imaging from the thermal camera made a powerful statement. Helicopters proved to be more suitable in leak detection surveys on gas gathering pipelines than that of fixed-wing aircraft.
The aerial leak detection technologies produce a significant increase in efficiency and productivity in managing the integrity of BP's gas gathering systems. While that improves business performance, perhaps more importantly is the fact that small gas leaks can be easily found before they become big ones. That reduces environmental damage and the potential for leaks to impact the public. The development and implementation of aerial leak detection in BP is being recognized as an integrity tool in providing a significantly improved integrity assurance to its gas gathering operations., One of prerequisite of any detection system is to get the requirement the risk analysis that estimates mainly the safety and environmental impacts of a loss of containment. From this prerequisite it is possible to consider a strategy for an early detection of a loss of containment, and to choose a method or a technology. Methods of detection belong to two main families:
External based Leak Detection System which used local leak sensors to generate a leak alarm. The main External based Leak Detection Systems are acoustic emission detectors, pressure detectors, fiber optic cable, vapor and / or liquid sensing cables;
Internal based Leak Detection Systems which used normal field sensors (e.g. pressure transmitters, flowmeters) for leak detection and leak localization. The main internal Leak Detection Systems are:
○
balancing systems (line balance, volume balance, compensated mass balance etc.);
○
Real Time Transient Model;
○
pressure/ flow monitoring;
○
statistical analysis…
The main External based Leak Detection Systems was studied internally through different evaluation and development programs and for some of them in operation.
The main findings were the followings:
The acoustic based detection is sensitive to external noises as well as some pipeline fluid (multi-phase, critical flow, transit phase) and pipeline elements (e.g. elbows, valves). This technology requires the management of high quantity of data, a significant tuning period, and many sensors connected to the pipeline. Distributed Acoustic Sensing (DAS) using the fiber optic cable media is currently used internally to detect real time intrusion.
The pressure emission detectors may be insensitive and require accurate pressure measurement. This technology is difficultly practical on short lines, gas or multi-phase pipelines with transient phases.
The vapor / liquid sensing cable technology needs to be physically close to the pipe to become wet in case of leakage. These sensitive cables should be replaced or cleaned after a leak. This technology is ne suitable easily for long distance application. Their retrievable capability with the implementation of pulling chamber every few hundred meters needs to be carefully considered. In addition, this technology is highly sensitive. This implies that false alarms may occurred in case of former contamination (presence of hydrocarbon). This technology is also sensitive to the soil disruption, fluid properties and is affected by the ageing (sensitive polymer alteration). However, this technology is suitable for short distance and for some leaks detection when there is no temperature variation between the fluid and the soil.
The Fiber optic solution was highly considered for a leak detection through several evaluation programs and, in particular two PIT (Projet d’Innovation Technologique) Projects. These two PIT projects were performed between 2015 and 2019 and presented to the following ADIPEC sessions
○
(Baque, 2017) 2017 Abu Dhabi International Petroleum Exhibition & Conference SPE-188669-MS Early Gas Detection
○
(Baque, 2020) 2020 Abu Dhabi International Petroleum Exhibition & Conference SPE-203293-MS Fiber Optic Liquid Leakage Detection
Note: Some of the paragraph parts of this manuscript are extracted from these two SPE documents referred (Baque, 2017) and (Baque, 2020). Other evaluation and development programs not presented previously are also presented in this manuscript., source_sentence: What occupational health hazards are anticipated with large construction projects during the energy transition?
sentences: institutionalized political structures to realize particular social objectives or serve particular
constituencies.  
**Non-hazardous waste:** Waste, other than Hazardous waste, resulting from company
operations, including process and oil field wastes disposed of, on site or off site, as well as
office, commercial or packaging related wastes [ENV-7].  
**Normalization:** The ratio of a quantitative indicator output (e.g. emissions) to an
aggregated measure of another output (e.g. oil and gas production or refinery throughput)  
[Module 1 _Reporting process_ ].  
**Occupational illness:** An Employee or Contractor health condition or disorder requiring
medical treatment due to a workplace Incident, typically involving multiple exposures to
hazardous substances or to physical agents. Examples include noise-induced hearing loss,
respiratory disease, and contact dermatitis [SHS-3].  
**Occupational injury:** Harm of an Employee or Contractor resulting from a single
instantaneous workplace incident that results in medical treatment (beyond simple first aid),
work restrictions, days away from work (lost time) or a Fatality [SHS-3].  
**Operating area:** An area where business activities take place with potential to interact with
the adjacent environment [ENV-4].  
**Operation:** A generic term used to denote any kind of business activity involving productrelated processes, such as production, manufacturing and transport. Note: the term oil and
gas operations used in the Guidance is intended to be broad and inclusive of other types of
product, such as chemicals.  
**7.5**, The broader work of the Directorate is carried out  
by its four standing committees.  
Safety Committee: This committee’s objective is the  
core of the Directorate: to eliminate fatalities and  
catastrophic process safety events in our industry.
In pursuit of this aim, the committee develops
and promotes the adoption of recommended
practices – a task it performs both on its own and
with partners and trade associations. The resulting
publications lay a foundation for both safety
and efficiency, and develops the motivated and
empowered workforce needed to provide the world
with clean, affordable energy.  
Highlights of the committee’s 2023 activities
include participation in events, the creation
of expert groups, issuing of publications, and
engagement in data reviews.  
- Events: In 2023, in addition to the regular
committee and subcommittee meetings,
the committee held diving workshops in
Rio De Janeiro and Paris. These meetings
championed local stakeholders and sought
to improve local diving performance. It also
hosted two Aviation Procurement Managers
Forums – one in London, the other in Houston  
– to address industry contracting behaviours  
and its impact on contractor resilience and
safety. In addition, the committee conducted a
Process Safety Workshop at the IOGP Summit
in Indonesia. Finally, at this year’s Offshore
Europe conference, IOGP Safety Director Steve
Norton moderated a panel on learning from, and
sharing, safety lessons.  
- Expert Groups: The committee established
three expert groups in 2023: two to revise
existing Reports (365 on land transportation
safety and 365-12 on in-vehicle monitoring), and
one to consider adoption and implementation of
recommended safety practices.  
- Publications: The committee issued ten  
guidance documents in 2023, covering critical
areas such as diving, aviation, and process
safety; see page 34 for a full list of publications.  
- Data reviews: The committee published its
annual compilations of safety performance data,
covering occupational, process, aviation, and
land transportation safety. IOGP has collected
safety performance data from its Members
since 1985 and our database is the largest in
the upstream industry, providing companies
with valuable information for benchmarking and
performance improvement.  
17, endotoxins and fungi. The authors recommended that
ongoing real–time measurement of these exposures be
carried out to identify boundary conditions, phases, and
settings with the highest pollutant release.  
12 — Health in the energy transition  
Good quality studies are needed on the health effects of
renewable energy sources. Such studies should include
populations and patients with well-characterized exposure,
high-quality information on outcome, and assessment of
potential confounders. While retrospective (e.g., case-control)
studies might produce useful results, prospective longitudinal
studies would provide the strongest evidence.  
Several LCA studies have been conducted for the different
technologies. These LCAs reported relative low levels of
emissions during the lifecycle of renewable sources of
energy. Few of these studies included a comparison with
fossil-based technologies. When more life cycle studies
become available it would be important to include them
in the literature review. While looking at the life cycle of a
certain technology, other health effects in the value chain
could potentially be identified (reference: UNECE on Carbon
Neutrality in the UNECE Region: Integrated Life-cycle
Assessment of Electricity Sources).  
As of December 2024, very few occupational and public
health hazards specific to energy transition technologies
have been identified. The energy transition is in an early stage
and will evolve quickly, and additional hazards unique to
energy transition activities may emerge; the specifics of this
are, at this time, uncertain.  
What is certain is that the energy transition will involve large
construction projects whose risks (and effective methods to
manage those risks) are well-known and understood. Existing
occupational health approaches will be able to manage
these risks effectively, provided the correct assessments are
conducted properly.
datasets: Sampath1987/offshore_energy_v1
pipeline_tag: sentence-similarity
library_name: sentence-transformers
metrics: cosine_accuracy
model-index: name: SentenceTransformer based on sentence-transformers/all-mpnet-base-v2
results: task: type: triplet
name: Triplet
dataset: name: ai job validation
type: ai-job-validation
metrics: type: cosine_accuracy
value: 0.9646831750869751
name: Cosine Accuracy
verified: no
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Created: 2025-10-12 17:38:57