bluuebunny/crossref_metadata_2025_split huggingface dataset:
Production of Waxy Low-API Oil from Deep Exploratory Well with Hydraulic Lift System - A Case Study
Authors: Kalwar Shuaib Ahmed , Awan Abdul Quddos 
Published: October 2022

Abstract
Heavy oil makes up approximately 15% of the world's remaining oil reserves. It offers opportunities that could be commercially viable and often rejected because of the inherent challenges of production. The main challenges for producing heavy oil include flow assurance, produced water separation and treatment, and additional heat and power requirements. In this project, a deep heavy oil well which did not produce naturally during Drill-Stem-Testing (DST) was efficiently revived using jet pump technology.
This paper presents the successful application during a pilot test in which hydraulic jet pumping technology was installed in a deep exploratory well to lift the heavy 11.5° API oil. The candidate well was a single-string completed well flowed from Sakessar-formation at negligible production rates during DST by nitrogen kick-off. Considering the preliminary testing results, jet pump (JP) technology was recommended as the suitable artificial lift (AL) method. The sliding-sleeve-door (SSD) was deployed as a part of initial completion and downhole JP was fabricated as per SSD dimensions. The pump was installed by slickline in the SSD housing and operated to assess the lifted production.
The light crude oil was used as the power fluid during initial phase of pumping. Later, produced fluid was re-injected for continuous lifting operation. The real-time monitoring was carried out for optimizing the parameters of the pump, such as injection parameters, nozzle-to-throat combination, and horsepower. The results of this pilot project demonstrated the successful implementation of jet pump on heavy oil reservoirs. The candidate well produced at an average rate of 300 BOPD at the injection rate of 2,750 BPD with injection pressure of 2,500 psig using an 11X nozzle-to-throat combination. The SSD JP installation was found to be an ideal method to lift heavy oil from the reservoirs, which did not produce by its natural energy. Further, when the well production will decline in future, operators can easily re-optimize JP performance by retrieving it using a slickline for modifying the nozzle and/or throat and re-adjusting the surface injection parameters. The hydraulic lift system enables the operator to improve production while conducting multiple rigless jobs and saving workover cost.
The key objective of this pilot test was to produce heavy oil with minimal OPEX in a deep well. The successful implementation and outcomes of the project identified dynamic applications of the hydraulic lift system technology. This confirmed jet pump as a proven well activation and lift solution even for low API crude and can be used on global practice.
Enhancing Well Integrity and Well Completion Flexibility with a Remotely Operated Multi-Cycle RFID Sub-Surface Isolation Valve
Authors: Munro Chris , Rodriguez Jonathan , Thain Terry , Di Mario Sabatino , Iglesias Danilo , Dornic Steven 
Published: October 2022

Abstract
Sub-surface isolation valves that form part of the well barrier envelope are required to have the most stringent qualification standards whilst also facilitating flexibility and functionality to complete the well safely and efficiently. By incorporating RFID technology into a hydraulically operated downhole ball valve, oil and gas wells can now be completed using remote electronic communication methods to actuate the barrier valve throughout the completion and well test phase.
The mechanical closure of the isolation valve, which is qualified to API 19v V1 CC classification, after any reservoir treatment can present significant well integrity problems should issues arise. To address this, an RFID microchip was to be incorporated into the work string as a contingency close trigger mechanism, should the shifting tool fail. Surface applied pressure cycles were sent to the isolation valve commanding it to re-open to allow well flow-back. Post well testing, an additional RFID microchip was deployed to the isolation valve to re-close it and form part of the well barrier envelope for P&A operations.
The well was completed and successfully tested by installing a set of completion equipment across the reservoir section. After the completion was installed the isolation valve was closed with a shifting tool isolating the reservoir section which allowed a safe well environment for running the upper completion. Having the electronic contingency option available significantly increases built-in contingency whilst reducing overall risk. With the reservoir isolated the upper completion was installed, pressure cycles were sent from surface to remotely trigger the valve to open. The short and specific sequence means that it is easily applied but hard to inadvertently trigger, therefore improving overall well completion flexibility and efficiency. The micro-hydraulic power technology on-board operates independently of hydrostatic pressure, ensuring that the valve opens regardless of the setting depth.
Once the well flow-back was successfully completed the valve was electronically closed by deploying an RFID microchip into the well for the final time, finalizing the P&A barrier envelope.
In conclusion, the combination of RFID on-demand multi-cycle technology with stringent sub-surface isolation valve qualification standards is now providing the industry with the integrity, flexibility, and reliability that it has long sought after, which adds up to a more robust and efficient well performance.
Shifting tools with built-in electronic triggers, advanced barrier valve qualification testing and high-performance sub-surface isolation valves are critical to well performance and safety within the oil and gas industry. This paper will focus on how these aspects were delivered to a super-major client to enable them to complete their well safely and efficiently.
Successful Through Tubing Perforation in Dual String Completion
Authors: Spagnolo Salvatore , Pollio Pasquale , Cappuccio Pasquale , Baldassarri Gianni , Carpineta Gabriele , Colombo Marco , De Clemente Alfonso , Picciani Alessandro 
Published: October 2022

Abstract
In a dual completed well, a through tubing perforation experience from geologic and reservoir study to job execution, is presented. Job targets have been the maximization of the production gain from one production string and the reduction of possible issues associated to charges detonation for the second string. The success of this job has been crucial for the life of a mature naturally fractured carbonate oil reservoir by opening new production opportunities.
The experience has started with a reservoir study followed by a log acquisition to confirm the geological hypotheses about the lack of production contribution from a level. Once the level potential was confirmed, a review of all the possible technologies available in the market, with related benefits and disadvantages, has been carried out in order to obtain the maximum result in terms of perforation efficiency and minimize the risk to lose integrity or accessibility in the well due to charges detonation. A complete explanation of the overall work flow is provided to clarify all the decision making process.
The first need to find an indication about the production contribution of a cased and cemented level through the hydraulic communication with a second perforated level open to production, can come from noise signals generated from a vertical flow path in formation. In fact, the vertical primary permeability or the natural system of fractures in a carbonate reservoir may represent a likely road to flow. The most suitable technology available to detect this phenomenon is the spectral noise log, which is a precise mean to discriminate about fluid movements in well or near wellbore according to its noise frequency. The second need to increase perforation efficiency and preserve one of the two strings from charges detonation in the second string, can be achieved by identifying a preferential direction at bottom hole and aligning the perforation guns to it. The analysis of real time data acquired through electric wireline from the "Magnetic Orientation Tool" coupled with a downhole electric motor controlled from surface, has allowed to fulfill this task.
The study presented offers a valid workflow to follow for through tubing perforation jobs to restore uneconomic wells life and provides a base for spectral noise log possible uses and innovative tools to add in perforation bottom hole assemblies to have more reliable information for improved job results.
Advances in an Integrated Analysis Workflow of Distributed Acoustic Sensing and Distributed Temperature Sensing for Water Injection Profiling on a Horizontal Well
Authors: Mahue Veronique , Dawson Peter , Jimenez Erick , Al Kiyoumi Ahmed , Al Tamimi Ahmed , Othman Alaa , Correia Gladwin , Alyan Mohand , Parihar Shardul 
Published: October 2022

Abstract
This paper describes advances in an integrated analysis workflow of Distributed Acoustic Sensing (DAS) and Distributed Temperature Sensing (DTS) for water injection profiling on a horizontal well, completed with Limited Entry Liners (LEL). The well is completed as an injector with Limited Entry Liner (LEL), MRC horizontal lateral made of 18 separated zones with packers, each with variable numbers of holes.
DAS and DTS data were acquired on coiled tubing, over an acid stimulation period followed by a water injection period. Previous analysis of the dataset, SPE-203065, focused on DTS warm-back models and highlighted challenges in the process; the use of the DAS data was limited.
Recent re-processing of the data using advanced acoustic signal processing techniques was performed to extract several flow characteristics. Both transient and steady state injection conditions were analyzed:
High-definition low frequency slow strain DAS was extracted over the shut-in to injection transient to compute an initial injection velocity profile as well as a stage level injection distribution across the liners. During steady state flow, acoustic denoising algorithms were applied to the DAS data in order to generate a spectral noise log of high signal to noise ratio (SNR) for the detection of all major injection points. Video animations were generated of spectral noise logs over time, to evaluate the dynamic behavior of the injection profile from start to end. The warm-back DTS data was analyzed for a qualitative assessment of the injection Finally, a quantitative injection profile was computed, and the results were compared against a separate PLT log at both stage and nozzle levels.
The results of the transient and steady state flow analysis converged and showed the highest water intake to occur over the heel-ward stages. The depths of highest rate of change in injection velocity, aligned with the strongest acoustic signals from the enhanced noise log. Inversely, the weaker acoustic outflow activities over the middle and toe sections aligned with the smaller velocity changes. The video animations showed a stable injection profile over time. The qualitative DTS analysis confirmed the overall DAS-based injection profile.
The comparison with the PLT injection allocation highlighted clear differences in the profiles. These are being discussed, as well as the possible causes for the discrepancies.
This analysis demonstrates the strength of an integrated DAS and DTS analysis workflow using both transient and steady state conditions. DAS array processing techniques enabled the extraction of high-definition transient thermal plumes, allowing for an early injection profile, which was further strengthened by high SNR spectral noise logging.
Paleo Structure Reconstruction to Reveal the Phenomenon of Paleo Hydrocarbon Contact- A Case Study on a Three Major Fields Onshore Abu Dhabi
Authors: Elila Abusaa Khalifa , Salahuddin Andi Ahmad , Fadipe Oluwaseun , Syofyan Syofvas , Al-Shamsi Saif Ghanim , Al-Naqbi Shaikha Obaid 
Published: October 2022

Abstract
Hydrocarbon presence has been observed in flank wells much deeper than crestal wells in several onshore fields in Abu Dhabi. To explain this phenomenon the integration of paleo-structural reconstruction, petroleum system analysis, and formation evaluation was used.
Thickness maps were created between the Early Cretaceous Kharaib-2 (KH-2) and several younger formations that represent paleostructure during the key tectonic and hydrocarbon expulsion events. Formation evaluation that integrates various types of logs, mud logs, geochemistry, core description and analysis have been conducted on several recent appraisal flank wells to confirm the presence of hydrocarbon below the Free Water Level (FWL).The formation evaluation, petroleum system analysis, paleo-structural reconstruction were integrated in order to understand the interesting phenomenon of paleo oil presence below the current FWL.
Structural reconstructionshows that various fields have structural crestslocated in the north-east during the Lower Tertiary and remained unchanged during peak hydrocarbon migration inthe Tertiary time.South-west tilting occurred as a result of the Zagros orogeny (Miocene), such that the Lower Tertiary structural crests now lies on the flanks of the fields. As a result of this tilting,hydrocarbon remigration and redistribution occurred and in places oil was replaced by water, but traces of residual oil are still present below the current FWL.This study shows that formation fluid sampling, core and log analysis indicate that the flank wells do not have better reservoir qualities that justify a deeper contact. The study also shows that there is no observed compartmentalization that separates the flank wells with crestal area. Structural reconstruction has explained the poor reservoir properties at the field crest, where it shows that today’s crest wells were flank wells at sometime during structural evolution, and diagenesis was the major playing factor impacting rock quality.
Modelling of the Upper Jurassic Petroleum System, Abu Dhabi: Implications for Play and Prospect
Authors: Fadipe Oluwaseun A. , Aitken John F. , Al-Salmi Huda S. , Laer Pierre V. , Vantala Aurifullah 
Published: October 2022

Abstract
As part of a reassessment of the Upper Jurassic Hanifa and Tuwaiq Mountain (TWQM) formations, regional basin modelling was undertaken on the Jurassic (‘Diyab’) petroleum system of Abu Dhabi to investigate hydrocarbon generation, migration pathways and to confirm the play fairway concept. Specific objectives were: To investigate the source rock kerogen transformation, maturity and generation potential,Assess the expected kitchen area in relation to charge and expulsion timing,Calibrate the model thermally and establish an event chart.
The model was built from surface to the Permian Khuff Formation to provide stratigraphic granularities to better understand the Upper Jurassic petroleum system. Sediment decompaction was modelled to illuminate structural evolution and associated properties through time. A total of 16 and 31 wells were used for temperature/pressure and porosity calibration respectively, to reduce uncertainties in the 3D model.Geochemical data filtering of outliers was performed on over 35 wells with Total Organic Carbon (TOC) data in the Hanifa-TWQM formation. The present-day map was refined with updated GDE maps used to estimate the original TOC maps following Peters et al. (2006) principles.
The model of the Upper Jurassic petroleum system is consistent with measured data including, well calibrated pressure, source rock maturity and temperature data. The original TOC map shows organic richness in the Western part of Abu Dhabi decreasing towards the east. The maturity output shows that from the Late Albian (100Ma) to present-day, the source rock is mainly within the late oil to gas window, showing almost complete conversion of kerogen to hydrocarbon with a transformation ratio of over 95%. Generation of hydrocarbon started as early as 150 Ma (Kimmeridgian), shortly after Hith formation deposition, however, it became significant during the Cenomanian (90 Ma). Simulation results indicate that the kitchen area is located in Western and South-Western Abu Dhabi where the original TOC, deposited in an intra-shelf basin, is highest compared to the upper slope and shelf andlean organic contents towards the east. The main reservoir zone (NNW-SSE shoal belt) is charged from the west with up-dip migration into Hanifa reservoirs both onshore and offshore, with some potential long-distance migration from the North-East Neo-Tethys shelf slope. The constructed petroleum systems event chart confirms the establishment of a working relationship between different petroleum systems elements and processes.
Refined TOC maps honoring environment of deposition as an input helped to improve the confidence in the modelling output that led to the validation of a working play with multiple leads identified. The results helped to subsequently update the play maps. In addition, the parameters generated assisted in de-risking identified leads. This provides a framework for detailed and informed prospect maturation studies.
Novel Approach for Porosity Quantification in Carbonates Using Borehole Images
Authors: Noufal Abdelwahab , Belouahchia Mounir , Amri Mohamed , Belayouni Nidhal , Petrov Alexander 
Published: October 2022

Abstract
Porosity quantification in carbonates rocks represents one of the main challenges in assessing potential carbonate reservoirs. Conventional well logs have low sampling rate and do not allowing to get an accurate porosity distribution. Currently, there are different methods for quantifying secondary and primary porosities by integrating different measurements and logs. Borehole image can solve the carbonate heterogeneity challenge when it comes to quantifying accurately the complex pore system distribution.
Single source of information – borehole image (BHI) is used across the full wellbore to calculate the contribution of matrix and heterogeneities to the total porosity and subdivide it into primary and secondary porosities. BHI is transformed into porosity image using only static image with normalized pixel values. Primary porosity refers to the porosity related to the matrix, while secondary porosity is related to all the heterogeneity regions extracted through the semantic segmentation module. For each row in the static image, pixels are classified as "heterogeneity" if they belong to a heterogeneity region, otherwise they are classified as "matrix". The primary and secondary porosity in the row are calculated as the sum of pixel values in the static image that belong respectively to matrix and heterogeneity, normalized by the total number of pixels in the row.
The technique has been used in this study to quantify the secondary porosity. Since there can be large porosity variation between consecutive rows, the results are presented in terms of a moving average. In this application it was used a window span of 1ft, although this can be changed depending on the length scale of heterogeneities in the borehole images. The outputs of this technique (image total porosity, primary porosity and secondary porosity curves) can be used in an empirical equation to improve permeability calculations, core calibration is required. The technique can give sufficient information to characterize the carbonate reservoirs in cases where the porosity system is dominated by one secondary porosity type, e.g. vuggy porosity or fracture porosity with low clay content and no borehole artifacts and performed with careful selection for the parameters and cut-offs.
Applying machine learning reduced these limitations as depending on using database of many wells characterizing the carbonate reservoirs it could be overcome following limitations in comparison with exciting techniques: The primary/secondary porosity distribution greatly cutoff method selection.Separation is possible to vuggy porosity and fracture porosity.Possibility to separate the isolated vugs from the connected vugs.
Integration of Static and Dynamic Data in Sequence Analysis and Its Application in Oilfield B, Middle East
Authors: An Fuli , Chen Xin , Xiao Dengyi , Li Xiaoliang , Ma Cong , Peng Bo , Zhao Bo , Qi Qunli , Wang Bo , Li Qiang , Liu Caiqin , Gao Xiaoli 
Published: October 2022

Abstract
The sequence stratigraphic framework based on the combination of core, lithofacies and logging curve cycles, sometimes hardly reflect the lithology and sedimentary changes between wells, and is inconsistent with seismic data and production performance. Through the integrated research of core, well logging, seismic data and reservoir engineering, this paper proposed an update method. The new method can effectively solve the geological challenges in exploration and development and provide a reliable geological basis for efficient production of the oilfield.
This method includes the following 3 steps, (1) identify the sequence stratigraphic boundary integrated the core and lithofacies analysis, and establish the well correlation sequence stratigraphic framework. (2) According to seismic and geological calibration, realize mutual constraint between wells and seismic and robust the sequence stratigraphic framework. (3) The sequence stratigraphic framework is optimized by using production dynamic data, which could grab the sequence stratigraphic framework more consistent with the deposition law.
The isochronous sequence stratigraphic framework established by this method in B oilfield of the Middle East truly restores the structural characteristics of the progradational strata of the main production layer in B oilfield, and the sequence boundaries match well between drilling data and seismic data. Under the control of the isochronous sequence stratigraphic configuration, the ambiguous results of the previous division in sublayers according to the lithological isopach were updated, which solved the problems of diachronous oil layer and disordered oil-water relationship in this oilfield. This study also provides an effective isochronous sequence stratigraphic unit for reservoir prediction in exploration and development.
Compared with the previous sequence stratigraphy research method in this area, the new method has two major advantages, (1) It complements the shortage of uncertain between wells and increases the accuracy for uncored interval. Furthermore, this method establishes a real isochronous sequence stratigraphic framework. 2) Combined with production dynamic data, the challenge of diachronous sublayers and confusion of oil-water relationship in the research results are avoided.