bluuebunny/crossref_metadata_2025_split huggingface dataset:
Progressing Cavity Pump Stainless Steel Impact in High Corrosive Environments Maximizing Economic Benefits in West Africa - Gabon
Authors: Yucel Ozhan , Levy Brenda , Ariza Gonzalez Gustavo Andres , Pilgrim Wayne , Soltys Tim Wayne 
Published: September 2021

Abstract
The combination of well conditions such as high levels of carbon dioxide (CO2, an average of 15%), 85% water cuts (WC), sand production, and heavy viscous oil is one of the biggest challenges for any artificial lift system (ALS). Progressing cavity pumping (PCP) is the preferred method for sand and heavy oil production; however, CO2 presence in the form of carbonic acid, generates corrosion and pitting on the carbon-steel section of the Progressing Cavity stators. This condition results in short run life for PC pumps with standard materials historically installed. Taking advantage of the corrosion strength properties that Stainless Steel (SS) material has, a new SS PC pumps were manufactured to be installed in highly corrosive application and then determine the increase on run life for those wells previously affected by corrosion. This paper describes a section of the results from the flow assurance improvement plan obtained by the installation of PC pumps with SS technology in terms of workover (WO) intervention savings and extended run life in nine wells operating in Gabon, West Africa.
This paper describes the methodology applied in the selection of the PCP models to be manufactured with Stainless Steel technology considering the dimensional restrictions the PCP would have due the casing size of the well completions where the PC pump would be installed, as well as the pump design requirements related to the expected flow rate in the wells historically affected by corrosion. In addition, the paper shows the screening done on the well candidates for the installation of SS PCP, based on historical well intervention data specifically associated to corrosion.
Since the installation of the SS PCP technology, the client has performed several acid stimulations that have required pulling the PC pumps out of hole and re-running them multiple times. Throughout these operations, the PCPs have had no failures requiring intervention. The installation of SS technology has improved well run life across all nine candidates by 584% on average. The SS PCP technology continue to run in all nine wells with no corrosion-associated interventions. For an average of 326 days across all nine wells, there have been no WOs performed on the PCPs. The reduction in WOs has helped to avoid production losses, downtime, and associated costs. SS PCP has shown great results extending PC pump run life over 6 times compared to previous applications and has proven to be a good option for larger flow rates in 5.5 in casing completions.
Geomechanical Implications of Reservoir Depletion vis-à-vis Post-Blowout Well Capping: A Gulf of Mexico Case Study
Authors: Michael Andreas 
Published: September 2021

Abstract
Reservoir depletion can impose major implications on wellbore integrity following blowouts. A loss-of-well-control event can lead to prolonged post-blowout discharge from the wellbore causing considerable reservoir depletion in a well's drainage area. Fractures initiated and propagated during well capping procedures following an offshore blowout can lead to reservoir hydrocarbons broaching the seafloor. In this paper, reservoir depletion is examined for a case study on actual deepwater Gulf of Mexico (GoM) parameters, evaluating analytically its impacts on in-situ reservoir conditions, hence assessing the likelihood of longitudinal or transverse fracture initiation during post-blowout well capping.
The reservoir rock is modeled as a porous-permeable medium, considering fluid infiltration from the pressurized wellbore. A novel analytical workflow is presented, which encompasses the major effects of reservoir depletion on the (i) in-situ stress state, (ii) range of in-situ stress states stable against shear fault slippage, and (iii) limits of tensile fracture initiation. The geomechanical implications of each individual effect on post-blowout well capping is discussed with the individual results illustrated and analyzed altogether on dimensionless plots. These plots are useful for engineers when making contingency plans for dealing with loss-of-well-control situations. The workflow is demonstrated on a case study on parameters taken from the M56 reservoir, where the April 20, 2010 blowout took place at the MC 252-1 "Macondo" well.
A smaller post-blowout discharge flowrate is shown to increase the shut-in wellbore pressure build-up at any given time-point following well capping, whereas an increased post-blowout discharge period leads to a lower shut-in wellbore pressure build-up, hence reducing the likelihood of a fracture initiation scenario and vice versa. Assuming a robust wellbore architecture, the most likely location of fracture initiation is the top of the M56 reservoir within the openhole section of the Macondo well. The critical discharge flowrate, an established indicator for fracture initiation during well capping using information from the post-blowout discharge stage is employed, pointing that fracture initiation is highly-unlikely for the assessed parameters. Nevertheless, fracture initation during post-blowout well capping remains a real possibility in the overpressurized, stacked sequences of the GoM. Finally, the model is extended to an "incremental"/multi-step capping stack shut-in imposed over a longer time-period (e.g. 1 day than abruptly over a single-step) to suppress the wellbore pressure build-up, if necessary to avoid fracture initiation.
Application of Air Cooled Heat Exchangers for Condensation of Natural Gas Liquids from Associated Petroleum Gas
Authors: Prokopev Mikhail , Vorobev Ilya , Rakhmangulov Yulay , Litvak Egor 
Published: September 2021

Abstract
The paper describes a method for increasing a yield of stock-tank oil by reducing liquid carryover with associated petroleum gas at crude processing facilities (CPF) of one oil field in Iraq by cooling the feed stream in air cooled heat exchangers. An integrated model of the field has been built consisting of: models of well tubings, models of wellhead chokes, an integrated model of oil gathering network, a model of air cooled heat exchangers, a model of material and heat balance of CPF. The air cooler performance in oil treatment has been asessed in accordance with ambient temperature profile. The main advantages and disadvantages of using the proposed scheme are shown in the article.
Considered in the article the air cooler has been originally designed and manufactured for use in another field. Therefore, one of the tasks was to validate the applicability of that air cooler unit in the oil treatment process for a field with facilities in-place. The novelty of the study lies in the non-standard use of an air cooled heat exchangers in the oil treatment.
The results of simulation of using air cooling units in oil treatment and the actual operation of air coolers showed increased output of crude oil at the CPF at low capital and operating costs.
Simultaneous Fracturing Operations: Successful Implementation and Lessons Learned
Authors: Algadi Otman , Mclaughlin Nathan , Wilpitz Louis , Farrell Tony , Gamadi Talal 
Published: September 2021

Abstract
Today’s multistage hydraulic fracturing operations often demand complex treatments that incorporate high injection rates along with high volumes of proppant and fluid. It is challenging, however, to execute these treatments in a time- and cost-efficient manner while still maintaining optimal treatment quality. This paper discusses the applicability and limitations of the simultaneous-fracturing (simul-frac) completion technique – a solution that offers considerable advantages to help operators meet increasing industry demands to "do more with less". Simul-frac involves hydraulically fracturing two or more adjacent horizontal wells simultaneously. This technique provides an effective solution to the challenges mentioned above.
A controlled field study was conducted on three four-well pads, on the same Permian Basin lease, with identical/matching well geometry, landing zones, lateral lengths, and treatment designs. Two pads were completed using a traditional zipper-frac operation, while one pad was completed using the simul-frac technique. Designed to analyze operational efficiency, overall completion cost and impact on well productivity, this study provides an unprecedented, precise comparison between simul-frac and traditional zipper completions.
The controlled field study provided valuable insight into how the simul-frac technique can affect operational efficiencies. Unlike zipper-frac operations, all four wells on the pad were being either fractured or perforated at the same time, so there was never a time when one or more wells sat idle. By fracturing two stages simultaneously, the crew was able to complete more lateral footage, compared to fracturing a single stage with zipper frac. This, in turn, shortened overall operational time to complete the pad by five days. These saved days reduced overall completion costs and allowed for earlier return on investment by putting the wells on production sooner.
Like traditional zipper-frac operations, simul-frac operations are performed by a single frac crew, requiring minimal equipment modification or alteration to treatment execution procedures. However, the simul-frac technique is a complex operation that presents unique risks and challenges, including: simultaneous injection of fracturing fluid into two wells at a higher total injection rate, higher proppant and daily chemical-consumption rate, two cranes and two wireline trucks on the same pad, and pairing of wells with different landing zones. These risks are manageable, and service providers can achieve the desired results by providing exceptional communication and expertise at the wellsite.
Simul-frac operations enable operators to execute multistage well stimulation faster and more efficiently. It introduces greater operational efficiencies by enabling the crew to operate at peak performance and by eliminating well idle time. These advantages translate to lower overall completion costs and reduced time to first production.
Corrosion Inhibition Enhancement for Surface O&G Operations Using Nanofluids
Authors: Mazo Camilo , Lopez Daniel , Forero Angela Marcela , Maya Andres , Lesmes Miguel , Cortés Farid Bernardo , Franco Camilo Andres 
Published: September 2021

Abstract
The main objective of this study is to develop and evaluate a nanotechnology-based material in combination with a commercial corrosion inhibitor (CI) as an alternative to reduce the corrosion rate in oil and gas facilities. The corrosion rate (CR) of surface facilities coupons was estimated using weight loss analysis as the response variable in the following study, showing that in absence of CI treatments, carbon steel (CS) coupon displays corrosion rates over 2.1 mm·y−1. Four commercial CI were evaluated at concentrations ranging between 35-50 mg·L−1 to select the most suitable treatment at surface facilities conditions, showing CR reductions of around 12.2 and 22.5% in both dosages for the best CI treatment. SiO2 and Carbon Quantum Dots (CQDs) nanomaterials were added to the selected CI at nanoparticle dosages from 50 to 500 mg·L−1 to improve the behavior of the selected treatment in presence of production brine. The effectiveness of the proposed nanomaterials is strongly dependent on the nanoparticle concentration, and hence, its dispersion degree onto the metallic surface, whereas low dosages in SiO2 lead to an increase in the CR, however, low dosages in CQD lead to a reduction of the CR. The proposed NanoIC was evaluated using 1M HCl solutions to study the role of the nanoparticles in strong acid media. The corrosion rates for CS outcrops in the presence of production brine with 1M HCl was 8.6 mm·y−1, which suggests an important role of mineral acids in the corrosion phenomena. In the presence of CI at a dosage of 35 mg·L−1, the corrosion rate was reduced by 10.7%. The CR of CS surfaces treated with brine and strong acid solutions in presence of NanoCI containing CQD nanomaterials at 50 mg·L−1 shows reductions of 28.6 and 74.2%, respectively. It can be concluded, the nanoparticles act as a corrosion inhibitor agent, reducing the interaction between the acid molecules and the steel surface by the formation of a thin film. This work opens the landscape into the incorporation of carbon-based nanomaterials in surface oil and gas operations for the reduction of the corrosion rate in the facilities during the production stage in the wells by the synergistic behavior between commercial corrosion inhibitor and nanoparticles.
Liners with Bulk Metallic Glass/High Entropy Alloy, Degradable in Formation Fluids for a Skin Free, Clear, Perforating Tunnel, Enabling Enhanced Reservoir Connectivity
Authors: Chen Roy Ting , Bennaceur Kamel , Markel Daniel , Harp Leonard , Harrison Casey , Shelton James , Hall Aaron , Kashyap Rashi , Ramesh Kris , Wilkinson Christian , Roy Indranil 
Published: September 2021

Abstract
A shaped charge for wellbore perforation includes a solid metal or powder liner pressed onto a case, sandwiching high explosives which may have varying thermal stability, dictated by the expected time of exposure and bottom hole temperature (BHT). It is common knowledge that post detonation, the liner-jet punctures the gun body and casing, continuing forward to perforate the formation until its eventual collapse. The jet debris is deposited on the crushed zone forming an impermeable skin and a slug at the end of the perforation-tunnel. This reduces fracture conductivity, and thus, production. Here we present a game changing innovation, the development of a shaped charge with a novel responsive liner. The jet created from our novel degradable liner, post detonation punctures the casing and progress to penetrate the formation until an eventual collapse. However, this system is designed so that, during detonation, a water disintegrable reaction product, bulk metallic glasses (BMG) and/or high entropy alloys (HEA), are formed. These degradable BMG/HEA or complexions decorate the grain boundaries and domain interfaces of the impermeable skin lining the crushed zone of the perforation tunnel as amorphous intergranular films (AIFs) and plug at end of the pathway. Interacting with flowback fluids the BMG/HEA promotes grain dropping, disintegrating the liner and carrot leaving behind a clean perforation tunnel, improving fracture conductivity thus enhanced productivity. In addition, a clear perf tunnel has zero skin value. As such, compared to a coated tunnel with gun and charge debris, it needs little or no acid to clean-up. This results in a demarked reduction of formation breakdown pressures with improved economics for the client. Last but not least this leads to cost reduction of authorized field expenditure (AFE) to support optimized performance of completion design allowing for increased production. CLEAR shaped charges have been qualified to customer specifications in field conditions and are ready to be commercialized. An extension of this technology is being applied to design charges for "Big-Hole" perforations, for the Plug and Abandonment (P&A) market where an effective cement squeeze, anchoring a plug effectively seals the wellbore, preventing the leakage of residual hydrocarbon and associated contamination and emissions.
A Back Allocation Methodology to Estimate the Real-Time Flow and Assist Production Monitoring
Authors: Chaves Gabriela , Monteiro Danielle , Martins Ferreira Virgilio José 
Published: September 2021

Abstract
Commingle production nodes are standard practice in the industry to combine multiple segments into one. This practice is adopted at the subsurface or surface to reduce costs, elements (e.g. pipes), and space. However, it leads to one problem: determine the rates of the single elements. This problem is recurrently solved in the platform scenario using the back allocation approach, where the total platform flowrate is used to obtain the individual wells’ flowrates. The wells’ flowrates are crucial to monitor, manage and make operational decisions in order to optimize field production. This work combined outflow (well and flowline) simulation, reservoir inflow, algorithms, and an optimization problem to calculate the wells’ flowrates and give a status about the current well state. Wells stated as unsuited indicates either the input data, the well model, or the well is behaving not as expected. The well status is valuable operational information that can be interpreted, for instance, to indicate the need for a new well testing, or as reliability rate for simulations run. The well flowrates are calculated considering three scenarios the probable, minimum and maximum. Real-time data is used as input data and production well test is used to tune and update well model and parameters routinely. The methodology was applied using a representative offshore oil field with 14 producing wells for two-years production time. The back allocation methodology showed robustness in all cases, labeling the wells properly, calculating the flowrates, and honoring the platform flowrate.
The Application of Data Validation and Reconciliation to Upstream Production Measurement Integration and Surveillance – Field Study
Authors: van der Bent Vincent , Amin Amin , Jadot Timothy 
Published: September 2021

Abstract
With the advent of increased measurements and instrumentation in oil and gas upstream production infrastructure; in the wellbore, in subsea and on surface processing facilities, data integration from all sources can be used more effectively in producing consistent and robust production profiles. The proposed data integration methodology aims at identifying the sources of measurement and process errors and removing them from the system. This ensures quasi error-free data when driving critical applications such as well rate determination from virtual and multiphase meters, and production allocation schemes, to name few. Confidence in the data is further enhanced by quantifying the uncertainty of each measured and unmeasured variable.
Advanced Data Validation and Reconciliation (DVR) methodology uses data redundancy to correct measurements. As more data is ingested in a modeling system the statistical aspect attached to each measurement becomes an important source of information to further improve its precision. DVR is an equation-based calculation process. It combines data redundancy and conservation laws to correct measurements and convert them into accurate and reliable information. The methodology is used in upstream oil & gas, refineries and gas plants, petrochemical plants as well as power plants including nuclear. DVR detects faulty sensors and identifies degradation of equipment performance. As such, it provides more robust inputs to operations, simulation, and automation processes.
The DVR methodology is presented using field data from a producing offshore field. The discussion details the design and implementation of a DVR system to integrate all available field data from the wellbore and surface facilities. The integrated data in this end-to-end evaluation includes reservoir productivity parameters, downhole and wellhead measurements, tuned vertical lift models, artificial lift devices, fluid sample analysis and thermodynamic models, and top facility process measurements. The automated DVR iterative runs solve all conservation equations simultaneously when determining the production flowrates "true values" and their uncertainties. The DVR field application is successfully used in real-time to ensure data consistency across a number of production tasks including the continual surveillance of the critical components of the production facility, the evaluation and validation of well tests using multiphase flow metering, the virtual flow metering of each well, the modeling of fluid phase behavior in the well and in the multistage separation facility, and performing the back allocation from sales meters to individual wells.
Empowering Technical and Soft Skills in Students and Young Professionals of the Oil&Gas Industry
Authors: Ardila Díaz David Enrique , Galvís William Genghini , Jaramillo Medina Sandra Juliana , Sanchéz Alejandro , Velásquez Sergio , Mantilla Cesar , Pastor Chacón Paola Andrea 
Published: September 2021

Abstract
To contribute to the construction of young professionals with an integral profile in which the competitive spirit is promoted through the resolution of a technological challenge applied to the Oil & Gas industry, under a scenario that demands a high degree of commitment and with the accompaniment of professionals with great experience in the industry.
In accordance with the data acquired and the program's target population, an appropriate methodology has been established for the development and strengthening of technical and soft skills. This methodology consists of four main phases: 1. Challenge construction 2. Best Teams selection 3. Challenge Resolution and 4. Results presentation. During the challenge resolution phase, participants have multiple technical and soft skills training sessions where experienced professionals share their knowledge and experiences related to the challenge theme in an environment of generational knowledge transfer.
During the last 4 years, around 120 participants from different cities of the country have managed to potentiate their soft skills and strengthen their knowledge in areas of the Oil & Gas industry such as unconventional, enhanced recovery, heavy oil, huff & puff, combustion had tests, wettability, waterflooding, among others and materialize it with the construction of an innovative technological tool. The best of each version was rewarded with their first work experience in the Oil & Gas industry where they were able to put into practice what they had learned during the program. Likewise, the continuous acquisition of valuable information about variables at the end of the program such as the knowledge areas of greatest interest for students and young professionals, the level of knowledge related to oil engineering and programming, the handling of a second language, and the skills acquired during the university training stage, has allowed strengthening the methodology of the"SPE en Sinergia" program, adjusting it to the current needs of the industry and placing the participants outside their comfort zone.
The development of the program and the results obtained are based on the identification of the strengths and weaknesses currently displayed by students in their final semesters and young professionals in careers related to petroleum engineering in Colombia and that in one way or another have become part of the reasons why their link to the professional world has become more difficult. This has enabled a way to identify opportunities for improvement and establish lines of action to promote the professional fast-track development of the new generations in a joint effort between industry and academia.