bluuebunny/crossref_metadata_2025_split huggingface dataset:
Synergies of Alkali and Polymers - Decreasing Polymer Costs and Increasing Efficiency
Authors: Hincapie Rafael E. , Borovina Ante , Clemens Torsten , Hoffmann Eugen , Tahir Muhammad , Nurmi Leena , Foedisch Hendrik , Hanski Sirkku , Wegner Jonas , Janczak Alyssia 
Published: October 2022

Abstract
Alkali injection leads to in-situ soap generation of high TAN number oil and residual oil reduction accordingly. We are showing that the performance of AP floods can be optimized by making use of lower polymer viscosities during injection but increasing polymer viscosities in the reservoir owing to "aging" of the polymers at high pH. Furthermore, AP conditions enable reducing polymer retention in the reservoir decreasing the Utility Factors (kg polymers injected / incremental bbl. produced).
Phase behavior tests were performed to understand the oil/alkali solution interaction and interfacial tension (IFT) was measured. Micromodel floods addressed displacement effects while two-phase core floods covered the displacement efficiency of alkali polymer solutions. We used aged polymer solutions to mimic the conditions deep in the reservoir and compared the displacement efficiencies and the polymer adsorption of non-aged and aged polymer solutions.
IFT measurements showed that saponification (41 μmol_g saponifiable acids) at the oil-alkali solution interface is very effectively reducing the IFT. Alkali phase experiments confirmed that emulsions are formed initially and supported the potential for residual oil mobilization. Aging experiments revealed that the polymer hydrolysis rate is substantially increased at high pH compared to polymer hydrolysis at neutral pH resulting in 60 % viscosity increase in AP conditions. Within the reservoir, the fast aging of polymer solutions in high pH results in increase to target viscosity while maintaining low adsorption owing to alkali and softened water. Hence, injectivity of alkali polymer solutions can be improved over conventional polymer flooding. The two-phase experiments confirmed that lower concentration polymer solutions aged in alkali show the same displacement efficiency as non-aged polymers with higher concentrations. Hence, significant cost savings can be realized capitalizing on the fast aging in the reservoir. Due to the low polymer retention in AP floods, less polymers are consumed than in conventional polymer floods significantly decreasing the Utility Factor (injected polymers kg/incremental bbl. produced).
Overall, the work shows that Alkali/Polymer (AP) injection leads to substantial incremental oil production of reactive oils. A workflow is presented to optimize AP projects including near-wellbore and reservoir effects. AP flood displacement efficiency must be evaluated incorporating aging of polymer solutions. Significant cost savings and increasing efficiency can be realized in AP floods by incorporating aging of polymers and taking the reduced polymer adsorption into account.
Intelligent Deepwater Advanced Solutions Hub for Value Maximization Throughout Asset Lifecycle
Authors: Ryu Sam , Chaney Carmela , Xu Wei , Hill Amanda , Zeng Yifei , Guha Amitava , Sun Wei , Garza-Rios Luis , Firmian Michael , Huang Xiaojun , Smith Benjamin , Ford Steven 
Published: October 2022

Abstract
The challenges with life-cycle management of an offshore asset, coupled with multi-discipline system engineering, and multiple competing project objectives provide an opportunity to seek a disruptive approach for maximizing value. The objective of this paper is to introduce ExxonMobil's new approach called intelligent Deepwater Advanced Solutions Hub (iDASH) where various engineering tools are strategically integrated to maximize value and improve decision quality utilizing advantages of latest digital technologies.
Establishing a cloud-based centralized hub with engineering tools that can generate holistic solutions is a novel and disruptive approach given the unique and complex nature of large-scale development and management of deepwater resources. As the energy industry goes through a challenging situation where more complex and competing objectives exist, the proposed iDASH can provide a new and unique approach to move in the right direction by leveraging integrated tools and data-driven technologies.
Offshore developments require a wide range of expertise areas including reservoir, wells, flow assurance, subsea, flowlines, risers, topsides, marine, geotechnical, costing, and project economics. Key challenges to asset life-cycle management include uncertainty from subsurface, limited number of alternative concepts, slow evaluation turn-around time, inability to integrate processes across multiple disciplines, and non-streamlined data transfer among different stages of a project. The iDASH approach proposes solutions by emphasizing the integration of tools, continuity among different stages of a project, and cross-discipline connectivity. Logically following typical project stages, iConcept, iDesign, iOperate, and iDecom are addressed as four pillars of iDASH to ensure value maximization.
Locating and integrating various engineering tools in a cloud-based centralized hub allows for cross-discipline collaboration, optimization, and faster cycles with either better solutions or multiple alternative options. Progress in this space can decrease capital expenditure (CAPEX) or increase net present value (NPV), resulting in faster monetization of an asset or a shorten payback time. Specific use cases and proofs of concept with different engineering tools demonstrate the feasibility of iDASH and value maximization. Specifically, a trade-space analysis for improving decision quality seeking an optimal concept is demonstrated as an iConcept tool. A riser optimization case is demonstrated as an iDesign tool. A mooring integrity checker is illustrated as an iOperate tool. Results validate that challenges in asset life-cycle management can be overcome and that the proposed disruptive approach offers quick, logical, strategic, and insightful means for managing the value maximization of an asset.
Innovative Upscaling First HT/HS Polymer Injectivity Tests Towards Multi-Well Pilots
Authors: Mahboobah Dyala Amin , Romero Carolina , Kaduluri Viresh , Ali Sawsan , Pimenta Gervasio , Al Saadi Haitham Ali , Luqman Abdulla , Altamimi Maitha Abdul Rahman , Huynh Francois , Gathier Flavien , Dupuis Guillaume , Garnier Olivier Francois 
Published: October 2022

Abstract
Following the successful results of the two Polymer Injectivity Tests (PIT) carried out within ADNOC Onshore fields, this paper focuses on the surface de-risking plan for the multi-well pilot's preparation. The objective is to ensure that the designed Key Performance Indicators can be met by the upscaled process design related to polymer solution quality, viscosity, concentration, injection rate and skid running time. The main challenges and lessons learnt from the two PIT operations were implemented in the polymer skid upgrade and helped define the polymer solution and equipment qualification criteria to meet the requirements set for the final skid's design and operation. This work is part of a larger de-risking strategy developed from laboratory studies to polymer field deployment, in preparation for hybrid SIWAP/SIMGAP (Simultaneous Injection of Water and Polymer / Simultaneous Injection of Miscible Gas and Polymer) EOR pilots in ADNOC Onshore.
This paper sheds the light on key operational findings and lessons learnt from the first High Temperature (HT) / High Salinity (HS) polymer injectivity tests conducted by ADNOC Onshore. The initial polymer injection implemented on two wells belonging to large ADNOC onshore reservoirs and their success, allowed the preparation of a pre-qualification process of the Polymer Injection Unit (PIU) and subsequent scale-up with improved features serving the challenging conditions of ADNOC Onshore fields. The preparation of the skid pre-qualifications tests is detailed including Performance Criteria set up, PIU Skid Pre-qualification process, upscaling PIU skid design features for the execution of the multi-well polymer pilot, followed by pre-qualification results, summary & conclusions.
The key outcome of this paper presents a new qualification scheme for deploying polymer injection technologies in the region under high temperature, high salinity and high H2S conditions. It also serves as a key contributor to the EOR strategy in the UAE and represents a vital benchmark for the future polymer EOR implementation across the region with advanced look-ahead on the key performance indicators for similar installations.
Anionic Nanoparticle Based Formulation to Control and Cure Moderate to Severe Losses
Authors: Alyami Noktan Mohammed , Wagle Vikrant , Alyami Abdullah Saleh , Kalgaonkar Rajendra 
Published: October 2022

Abstract
Moderate to severe losses can be treated using the loss circulation composition involving nanomaterial-based dispersion and a chemical activator. The nanomaterial employed is an environmentally friendly type of nanosilica. The composition facilitates delayed gelling of nanomaterial-based dispersion. One key benefit of this technology is that it can place the composition into the target loss circulation zone before the nanomaterial-based dispersion gels up. This ensures that the treatment fluid does not set prematurely before reaching the target zone. It is possible to effectively use the newly developed system up to 300°F.
In this study, experiments have been carried out on three different types of nanomaterials that have varying surface charges and particle sizes. Two of the nanomaterials have negatively charged nanomaterial-based dispersions and particles measuring 5nm and 17nm in size, whilst the remaining nanomaterial has a positively charged nanomaterial-based dispersion and particles that are larger than 17nm. Moreover, two different types of chemical activators have been employed, namely organic and inorganic activators, whilst their impacts on gelling times have also been assessed. The gelling time experiments were carried out at four different temperatures starting from 150 °C to 300 °C with increment of 50 °C in each experiment. This research also examined the impacts of activator concentration and different shear rates on the gelling times of the three nanomaterial-based dispersions, whilst permeability plugging tests were carried out using 2mm slotted disks in order to assess their effectiveness in controlling moderate to severe losses.
Extending the Capability of Electromagnetic Corrosion Inspection Beyond Five Tubulars
Authors: Dai Junwen , Fouda Ahmed , Wang Xusong , Hill Freeman 
Published: October 2022

Abstract
Well completions typically consist of multiple nested tubulars that provide the necessary well structure to ensure integrity for production and to protect the aquifers from contaminants. Monitoring the condition of multiple strings of tubulars is crucial in oil and gas wells and environmental management. For wells that had to drill through multiple pressure regimes, or with geomechanical and geology challenges, or those in highly corrosive environments, the number of well casings may exceed five pipes to provide better protection. Surveillance of pipe integrity in such wells is extremely challenging. A multifrequency electromagnetic pipe inspection tool with multiple transmitter and receiver arrays was designed to accurately estimate the individual wall thicknesses of multiple tubulars. In this paper, we present a workflow to process the measurements and demonstrate the performance of this tool to inspect the integrity of more than five nested pipes.
The tool is based on electromagnetic eddy current principle and comprises multiple transmitting and receiving coil antennas with different spacings and operates in continuous-wave mode at multiple frequencies. To increase sensitivity to outer pipes, receiver coils are placed at larger spacings from the transmitter, and low frequency excitation is used. Feasibility studies show that the measurements are sensitive to the outer pipes beyond the fifth pipe, suggesting the possibility to inspect all nested pipes in one single logging run. An advanced data processing workflow including multi-zone calibration and model-based inversion is executed to estimate the tubulars electrical conductivity and magnetic permeability, wall thickness, and eccentricity. In the process of inversion, a regularization term is added to the cost function to obtain a more accurate solution based on the corrosion profile on the pipes as inferred from the data.
The capabilities of the tool in wells with more than five pipes are demonstrated using synthetic data. The tests demonstrated accurate estimation of the location and severity of corrosion in each one of a multiple pipe configuration. This also reveals that the tool can detect various kinds of corrosion in wells with up to seven concurrent strings of pipes.
This is the first time a corrosion inspection tool is shown to have the capability of estimating the individual thicknesses of well completions with more than five pipes. Such capability eliminates the necessity to pull the tubing and provides a complete picture on the integrity of the well casings. The information provided by this tool can significantly minimize inspection time and cost and improve the overall efficiency of well intervention operations.
Improving Drilling Efficiency through Heterogeneous Formations and Reduce Stick Slip Levels after the Implementation of Self-Adjust Depth of Cut Technology in Oil Well
Authors: Alkhazal Sarah Abdulla , Mahdi Munir Jelal , Barrera Jonathan Lee Quintero , Aljishi Mohannad 
Published: October 2022

Abstract
This paper describes the improved drilling efficiency of 8-1/2-inch PDC bits with self-adjusting depth of cut control technology, and its achievements in minimizing the level of vibrations and meeting directional objectives through heterogeneous formations.
An 8-1/2-inch PDC bit equipped with self-adjusting depth of cut control was selected to improve drilling efficiency and mitigate high level of vibrations encountered through a challenging directional application. This selection was made due to its ability to autonomously adjust the amount of depth of cut control and adapt to the current environment. Observations of drilling and vibration data revealed the benefits of the technology in delivering the directional section through multiple formations with excellent performance and successfully mitigating the different type of vibrations.
The 8-1/2-inch self-adjusting bit was used in three wells to deliver four directional sections. The implemented bit was able to reduce drilling costs by attaining a 10 % improvement in rate of penetration, a 36% reduction in torque variation, and 100% completion of each run with zero NPT. In addition, the adaptive technology significantly reduced stick slip vibration and prolonged downhole tool life by its unique dynamic self-adjusting depth of cut control. A comparison study of the effects of lithology changes on different bit types showed the capability of this unique technology to overcome formation challenges and obtain the best drilling efficiency.
The introduction of the only PDC bit in the industry that can autonomously adapt its level of depth of cut control to the current drilling environment successfully improved drilling efficiency, delivered higher drilling performance, and minimized vibration levels.
First Deployments of Friction Adjustable Stabilizer Technology in the GCC
Authors: Yudhia Denya Pratama , Rabis Philippe , Couzigou Erwan , Al-Marzouqi Adel , Al Ameri Fahed Salem , Ryan Gerry 
Published: October 2022

Abstract
The paper seeks to address the challenges of drilling BHA dysfunction which impacted the drilling performance in Abu Dhabi Offshore. Drilling operations experience vibration and stick-slip which limited the ROP and often led to BHA failure cases. In addition, challenging trip out and casing running were observed which indicated unsatisfactory borehole quality. Enhancement of the drilling BHA is required to reduce vibration and improve borehole quality. In reference to study of Self-Excited Stick-Slip Oscillations of Drag Bits by Thomas Richard in 2001, reducing the amplitude of the vertical oscillations should lessen (if not eliminate) the severity of the coupling between the two modes of vibrations, and therefore, of the self-excited vibrations. This could be achieved by minimizing the upward motion of the BHA, by appropriately increasing the lateral friction between the BHA and the borehole wall. Appropriately means "without affecting too strongly the overall efficiency of the system." Friction Adjustable Stabiliser Technology (FAST) is designed with patented features to achieve the above-mentioned BHA condition. A series of runs with FAST incorporated into RSS drilling BHA were planned. A set of KPIs were put in place to evaluate BHA performance. The drilling BHA was simulated to obtain the optimum tool placement, in collaboration with BHA providers. The drilling results were then analysed and compared with analogue wells to demonstrate the deployment of this technology. The deployment of FAST was conducted in 12-¼″ and 6″ hole sections with a total of 7 runs. FAST was run with various RSS systems with low level of vibration in the majority of the runs and proven to minimize vibration/stick-slip during drilling by acting as the BHA contact point and delivering consistent and sufficient friction. As a result, the drilling BHAs were able to deliver the objective to TD and avoid additional trips due to BHA failure. Borehole quality was evaluated through trip out BHA and casing/tubing RIH performance. There is still room for improvement in trip out performance, as backreaming was still required in most of the runs. However, positive impact to performance of RIH casing or lower completion from good quality borehole drilled by BHA with FAST was confirmed from all runs. The saving from fit-for-purpose BHA design on average is 2 days, considering the average NPT for trip out the BHA. In addition, improvement in trip out performance in 6″ section is 0.4 days. Considering above, total saving from 6″ section is 2.4 rig days. The detailed BHA performance analysis and operation feedback from subsequent wells will be beneficial to assess the suitability of this technology to overcome future drilling challenges.
New Low ECD OCIEF (Organophilic Clay-Free Inverted Emulsion Fluid) Weighted with Manganese Tetroxide Showed Superior Performance in Different Fields: Success Story of Drilling with Ocief in High Overbalance Environment Without Downhole Problems, Stuck Pipe Events and Non-Productive Time
Authors: Wagle Vikrant , Yami Abdullah , AlMoajil Abdullah , Onoriode Michael 
Published: October 2022

Abstract
This paper describes the success of using a new low ECD OCIEF in different Gas Reservoirs at elevated temperatures and with differential pressures up to 4,500 psi. The objective of the paper is to highlight the superior performance of OCIEF during the execution which led in overcoming challenges in such type of environment without compromising performance
This paper describes several applications where the OCIEF has been deployed achieving optimum drilling performance while minimizing the formation damage of the reservoir. Consequent applications showed how the implementation of work methods, best practices and optimized drilling parameters allowed to successfully drill the section without downhole problems and pass the Production Screen Test (PST) and finally allow a proper clean-up while producing the well.
Initial deployment of the fluid system shows the required fluid specifications to properly address the slim hole challenges in high overbalance environment. Field implementation and continuous fluid performance improvements are reported in this paper, showing how the fluid system helped to successfully complete numerous wells in different fields. The versatility of the fluid system in terms of rheological profile and thermal stability and the minimized formation damage characteristics made the OCIEF as the sole non- aqueous fluid solution applied in Gas Reservoirs under extreme overbalance conditions. No more non- productive time has been experienced over the entire drilling campaign performed with OCIEF.
The new low ECD OCIEF (Organophilic Clay Free Inverted Emulsion Fluid) designed a new and enhanced polymer package, without organophilic clay and lignite and with acid soluble manganese tetroxide as weighting agent replaced the usage of water-based fluids without compromising production and with improved performance in extremely challenging gas wells. The proven performance is opening more boundaries for future applications in similar wells.
Foam Assisted Lift Journey in PDO
Authors: Ghaempanah Babak , Al Azri Basel , Veeken Cornelis , Al Rashidi Ahmed , Daraai Thabit , Cruceru Dragos , Al Hasani Said 
Published: October 2022

Abstract
Foam assisted lift (FAL) is one of the common deliquification techniques that is applied in different forms. However, achieving sustainable improved performance in practice from case to case is yet a challenge. This paper shares the journey that PDO has gone through so far in assessing and applying foam assisted lift technology, and the strategy that is emerging from this journey. The paper sheds light on challenges and lessons learned by sharing both successful as well as unsuccessful cases to provide a comprehensive picture. Proper candidate selection as well as selecting different implementation methods for different cases are the key learnings and yet challenges in practice that this paper elaborates on.