bluuebunny/crossref_metadata_2025_split huggingface dataset:
Rotating 6 Axis Survey Measurement and it's Effect on True Vertical Depth Accuracy, a Study of Sag Correction and Misalignment While Drilling
Authors: Lowdon Ross , Brands Sjoerd , ElGizawy Mahmoud , Rawlins Sheldon 
Published: September 2022

Abstract
Definitive dynamic 6 axis surveys provide continuous MWD quality measurement while drilling. This poses a challenge in terms of misalignment (relative to the borehole) correction when compared to traditional static survey measurements where misalignments are well understood and can be easily compensated for. The increased frequency of surveys allows for the possibility of significant systematic TVD errors if a static misalignment (SAG) error is applied unilaterally to the definitive dynamic surveys.
This paper outlines how we can measure misalignment in definitive dynamic surveys, what the magnitude of those misalignments are and their impact on a wells TVD.
The misalignment of Definitive Dynamic Survey measurement with respect to the borehole is a complex problem, as the BHA is under dynamic load and rotation as measurements are being made. As such a dynamic BHA model needed to be developed where the input parameters to the drillstring (such as RPM, Weight on Bit, and mud properties) and the downhole movement data available from the MWD and Rotary steerable tools are combined to recreate down hole conditions. The BHA which was run is then modelled dynamically to establish what borehole misalignment is present. This information is then evaluated to see what localized and summed effect this misalignment has on the inclination derived in the Definitive Dynamic Survey and therefor the impact on TVD and lateral well placement.
The results of this study will establish the validity of mis-alignment corrections to be applied to definitive dynamic surveys, it will also allow for further insight into BHA behavior to be made and improved dynamic models to be developed due the new Realtime surveying density that is possible with taking surveys every 20 seconds while drilling.
The original theory of random misalignment will be tested with high density downhole data to build a more complete picture of the BHA motion with insights into borehole quality and true well placement becoming possible. This could fundamentally improve TVD errors, with a dramatic reduction in the residual error for SAG corrections having a particular impact on long high angle sections of a given wellbore.
Definitive dynamic surveys are novel in that definitive surveys are taken while drilling rather when stationary. The analysis of these high-density surveys provides new insights into borehole quality and geometric well placement. Adding in downhole shock and vibration data with surface information it is possible to see how the BHA is behaving in the borehole and resolve the issue of borehole misalignment and ultimately tool accuracy.
Semi-Analytical Model of A Multi-Well System with well Interference During Underground Gas Storage
Authors: Chu Hongyang , Ma Tianbi , Jiao Yuwei , Zhu Weiyao , Zou Jiandong , Pan Yuewei , Gao Yubao , Lee John 
Published: September 2022

Abstract
Underground gas storage (UGS) is an important source for regulating natural gas supply. The large injection or production rate causes well interference in UGS to be particularly serious. Current well testing workflows for UGS assume a single well. This paper proposes a novel multi-well solution and related analysis method to analyze targeted well performance in a multi-well system. On the basis of the constant rate solution, Laplace transforms, and the superposition principle, we obtained multi-well solutions for transient flow. A systematic validation of the proposed method was conducted using a commercial numerical simulator for cases of gas storage and recovery process in UGS. Results show that the long-term gas injection and production process in UGS further exacerbates the influence of formation heterogeneity and interference. As adjacent wells are producing, the pressure derivative finally exhibits pseudo radial flow of the multi-well system under the influence of well interference. The horizontal derivative value is related to the dimensionless production rate of the target well, adjacent wells, mobility ratio, and the traditional 0.5 value. When adjacent wells are injecting, the last flow that appears in the derivative curve shows a drop-off feature. Our methodology applied to analysis of UGS performance in the Hutubi gas reservoir in China provides better estimates of the in-place natural gas resource and formation properties in this multi-well system. The methodology also provides a consistent and direct analysis of reservoir performance when "well interference "effects are observed.
The Positive Effect of Geomechanics on Adsorption and Transport Processes During Co2 Huff-N-Puff in Organic Shale
Authors: Zhang Wei , Mehrabian Amin 
Published: September 2022

Abstract
A thermodynamically rigorous constitutive model is used to describe the full coupling among the nonlinear processes of transport, sorption, and solid deformation in organic shale where the pore fluid is the binary mixture of carbon dioxide and methane. The constitutive model is utilized in a numerical solution that simulates injection of carbon dioxide in shale before producing carbon dioxide and methane from the same. The solution considers advection and diffusion as viable mechanisms of pore fluid transport where the latter comprises molecular, Knudsen, and surface diffusion in ultralow permeability shale. Results indicate that complete or partial exclusion of the coupling between sorption and solid phase deformation from the solution would result in underestimation of carbon dioxide storage capacity and natural gas recovery factor of the rock. In this aspect, sorption-induced deformation and strain-induced changes in gas sorption capacities are all conducive to both outcomes.
Rock Physics and Machine Learning Analysis of a High-Porosity Gas Sand in the Gulf of Mexico
Authors: Suleymanov Vagif , El-Husseiny Ammar , Glatz Guenther , Dvorkin Jack 
Published: September 2022

Abstract
Rock physics transforms established on the well data play an important role in predicting seismic rock properties. However, a data-driven approach, such as machine learning, can also estimate the targeted outputs from the well data. This study aims at comparing the accuracy of rock physics and machine learning analyses for the prediction of the P-wave velocity of porous rocks at the well log scale by employing the well data from the Mississippi Canyon, Gulf of Mexico.
Rock physics diagnostics (RPD) was used as a physics-driven methodology for predicting the P-wave velocity, while artificial neural network (ANN) was used as a machine learning approach. To train the neural network, the well data were divided into two sections where the ANN model was optimized on the upper well data interval and tested in the lower interval. During the rock physics analysis, the lower interval was employed to compare the obtained results from the physics-driven and data-driven approaches in the same well interval.
Based on the results from RPD, the constant cement model with a high coordination number describes the well data under examination. The established rock physics model is used for predicting elastic properties of rocks, including the P-wave velocity from measured petrophysical properties, namely porosity, mineralogy, and the pore fluid. However, the mineralogy input, such as the clay content, was missing in the well data. Therefore, the clay content was calculated from the gamma ray log and used in the rock physics model established. On the other hand, the ANN model was developed and tested using well log inputs such as porosity, gamma ray, and resistivity logs. Results showed that the accuracy of the machine learning model outperforms that of the rock physics model in the prediction of the P-wave velocity. In particular, a correlation coefficient (R) of 0.84 and absolute average percentage error (AAPE) of 2.71 were obtained by the ANN model, while the constant cement model reached CC of 0.65 and AAPE of 4.07. However, one should be aware that the computed clay content from the gamma ray log was a major factor in obtaining low CC compared to the ANN model as it significantly introduced uncertainty in our computations.
Nanotechnology Extended Release Asphaltene Inhibitor System/Formulation for Improved Squeeze Applications
Authors: Jayawickramage Rangana , Powell Kristin , Nguyen Bradley , Guraieb Paula , Tomson Ross , Salim Abdullah Dalia , Odeh Nadir , Punnapala Sameer , Pimenta Gervasio , Mark Fonseca Rahul 
Published: September 2022

Abstract
Mesoporous silica nanoparticles (MSN) are synthesized in the presence of asphaltene inhibitors such that asphaltene inhibitor is loaded within the nanoparticle carrier platform resulting particles with 50-400 nm average particle diameter. Particle size distributions, imaging of particles, surface charge measurements, and specific surface area measurements confirm successful synthesis. Synthesis parameters are customized to target particle size distributions, attachment to rock, inhibitor release rate, stability with time, temperature, shear and easy pumpability and no formation damage. Modification of particle surface chemistries was successful allowing for suspension in either aqueous or oil-based formulas and facilitate rock attachments. Further, these asphaltene inhibitor-loaded nanoparticles are synthesized in either an aqueous or oil solvents for customized squeeze design. Also, batch testing and measurements of core test effluents indicate that asphaltene inhibitor is successfully contained within nanoparticle carriers. These formulations have a 3x increase in treatment time compared to commercial asphaltene inhibitors in labscale core testing. This is a successful proof of concept that such nanoparticle systems can be pumped into reservoir material and provide a controlled release of asphaltene inhibitor.
Agile – Scrum Based Approach to Identify and Evaluate Opportunities in a Mature Field
Authors: Kannan Subash , Natasha Jeansonne , David Work 
Published: September 2022

Abstract
Agile, a Scrum-based project management approach, is typically used in the software development arena, but also has applications in the oil and gas industry. This paper demonstrates the feasibility of this project management approach when applied to a full field, subsurface development evaluation. Using this method for a multi-reservoir evaluation improved the quality and speed of decision making. The Agile methodology uses the Scrum process – a term borrowed from rugby where teams push the ball towards the goal together. We share a case study discussing the objectives, best practices, and lessons learned from evaluating a Gulf of Mexico producing field. Twelve reservoir intervals were thoroughly evaluated and ranked in only five months, a process that could normally take one to two years to complete.
The blueprint of the process involved Scrum lanes, sprints, and Minimum Viable Products (MVPs). Sprint meetings were held daily with the three core team members. Weekly Scrum lane updates were provided to stakeholders to show progress and potential opportunities identified. The Scrum lanes funneled the technical workflow into an iterative process across specific disciplines for multiple reservoirs, which culminated into economic evaluations. A Scrum lane tracker was provided to the management team for weekly updates. Weekly sprints helped the team create the priority list. In cases when there no reasonable MVP was identified, the evaluation was moved to a lower priority to allow refocus on other prospective intervals. The identified opportunities were then ranked using a pyramid hierarchy that was based on capital and regulatory requirements.
Using the Agile, Scrum-based approach for the analysis of multiple reservoirs in an offshore field proved to be highly advantageous. Even with a compressed timeline and small team, a high-quality technical and commercial product was delivered in a fraction of the typical project timeline. The level of technical detail when coupled with the relentless opportunity pursuit, frequent MVP results, and overall high energy level resulted in a positive and productive work environment that was acknowledged by the core team, asset peers, and management team. The success of this pilot project can be used and adapted as a template for future asset evaluations.
Successful AICD Application to Reduce Water Production in a Heavy Oil Greenfield
Authors: Pedroso Carlos A. , Rocha Paulo , Araujo Zaque 
Published: September 2022

Abstract
This paper aims to describe the successful use of AICD in Atlanta field, Eocene heavy oil reservoir located in ultradeep waters offshore Brazil. The HZ-OHGP with AICD installation and initial Atlanta's performance has been well described in previous papers (SPE-206153, SPE-199325, OTC-29757). This article will focus on the production analysis after 20,000,000 bbl produced in the field.
The use of AICD for reducing water production has been extensively reported in literature (SPE 187288-PA, OTC-27992, SPE-174341-MS, SPE-195617, OTC-30445, etc.). Atlanta's application, however, differs from others mainly for two reasons: first, and more important, the HZ-OHGP with AICD was installed in a green field, in the 3rd well of the Early Production System (EPS), before any water had been produced in the field. Second, all 3 wells were completed with a massive amount of oil and water tracers (6 for oil and 6 for water per well), which allows for in-depth analysis of the AICD performance, and an unprecedented comparison with 2 offset wells.
The results from the tracers indicate that the AICD achieved both objectives: equalizing the flux in the reservoir to the well and reducing water production, which, in Atlanta's EPS was especially important since the FPSO producing in this pilot project has limited water treatment capacity.
After 45 months and the total EPS production of more than 20.000.000bbl for the 3 wells, the one completed with AICD still has the lowest BSW, the highest production rate and the highest cumulative production. These results will be deeply discussed in this paper.
Reinjection of Produced Water with High Salinity After Applying a Novel Treatment Method
Authors: Mathews Tanya Ann , Hascakir Berna 
Published: September 2022

Abstract
This study investigates a novel method to reduce TDS in produced water to enable safe and effective reuse in hydraulic fracturing. In particular, we test whether evaporative technology can effectively separate dissolved solids from high-TDS wastewater produced in abundance in oil fields.
Experiments were conducted with distilled water (E1) and produced water (E2), among which the distilled water experiment served as a control experiment for comparison purposes. Produced water (PW) samples were taken from the Southern Midland Permian Basin. An evaporative air cooler was used for the experiments. We replaced the cellulose filters in the air cooler with Pozzolan filters as the latter is resistant to corrosion and can be easily regenerated. The filter was wet continuously by the water sample stored in the reserve tank of the evaporative cooling unit. Each experiment was run for 4 hours. To determine the system’s cooling efficiency, we measured inlet and outlet ambient temperatures, wet-bulb temperatures, dew point temperatures, and relative humidity every hour using a temperature humidity meter. In addition, the water samples were characterized before and after each experiment by measuring total dissolved solids (TDS), pH, particle size, and zeta potential.
Our experiments showed that E1 had a cooling efficiency of 21% while E2 had 16% in the laboratory environment, which does not have continuous airflow in and out like on the wellheads in an oilfield. Hence, we expect higher efficiencies in an oilfield. The reduction in cooling efficiency from E1 to E2 is primarily attributed to the precipitation of the suspended solids on the filter. Therefore, we recommend removing suspended solids from the water before filtering it through the evaporative cooling unit. In addition, we observed that the amount of water treated through the process was slightly less for E2 (35% of the initial volume) than E1 (40% of the initial volume). We believe this treatment efficiency can increase further if the experiments are conducted on the wellhead rather than in a laboratory. Furthermore, we observed a reduction in particle size and an increase in zeta potential in the reserve water post-experiment. In other words, the TDS was mainly eliminated and remained in the untreated water body, while the treated water contained significantly less amount of TDS with higher stability.
We prove that evaporative cooling is a novel method for low-cost TDS reduction. As a result, it can be instrumental in solving the decade-long problem of large volumes of high TDS wastewater produced during hydraulic fracturing, particularly in the Permian Basin.
A Novel Polysaccharide Friction Reducer That can be Used with Water of All Salinity Levels
Authors: Siddiqui Farhan , Emrani Arezoo 
Published: September 2022

Abstract
This work was carried out to compare a new system with synthetic polyacrylamide friction reducers used in the oil and gas industry. The most common friction reducers used for fracturing are anionic, and hence have limited use in high TDS brines especially in brines containing di and trivalent metal ions. When the new system is properly optimized, we were able to achieve a very efficient and low-cost carrier fluid that can give maximum friction reduction and effectively suspend proppant during a fracturing treatment.
The new technology for unconventional fracturing is a versatile and multifunctional product that can be pumped with the traditional frac equipment used in the industry for pumping powdered dry guar gum on the fly. The main objective of this work is to develop a new friction reducer formulation to aim to reduce cost and improve retained conductivity. This product is shown to be Gulf of Mexico green and biodegradable. Conventional breakers can be used to break these fluids and give excellent retained permeability on cores. The new system gives good friction reduction even at a very small dosage of 1ppt to 4ppt or 0.25-1.0 gpt, and it can be used similarly to guar gum as a linear gel or can be crosslinked with boron to yield better viscosity and proppant transport. The presence of iron in water can seriously affect the rheology and friction of traditional friction reducers, high viscosity friction reducers, and even guar systems. Laboratory studies have shown that this new product is very effective even in water containing very high concentrations of Ferric iron. Case histories from wells treated with this system containing high divalent and trivalent metal ions confirm the laboratory findings. In countries where equipment to pump on the fly is not available, the new system can be used as a slurry also.
This paper will present laboratory test results of using a new polysaccharide friction reducer with similar friction reduction to a Polyacrylamide Friction reducer and the proppant suspension of a crosslinked guar system. This system can be used with fresh or saline waters containing high concentrations of divalent and trivalent metal ions. This gives the operator the flexibility of using any water, and the water analysis step before a frac job can be eliminated.
Development of Multi-Stage Fracturing System and Wellbore Tractor to Enable Zonal Isolation During Stimulation and EGS Operations in Horizontal Wellbores
Authors: Fleckenstein William , Miskimins Jennifer , Kazemi Hossein , Eustes Alfred , Abdimaulen Dias , Mindygaliyeva Balnur , Uzun Ozan , Amini Kaveh , Hill Tom , Mailand Jason , Henschel Robert , King George , Ortiz Santos , Keyes Cullen 
Published: September 2022

Abstract
This paper discusses the progress on a project funded by the DOE Utah FORGE (Frontier Observatory for Research in Geothermal Energy) for the development of a subsurface heat exchanger for Enhanced Geothermal Systems (EGS) using unique casing sleeves cemented in place and are used first as a system for rapid and inexpensive multi-stage stimulations and second to perform conformance control functions at 225 °C. The proposed sleeves will use a single-sized dissolvable ball to open for fracture stimulation. After stimulation, and once the balls dissolve, the sleeves are open for immediate fluid injection. A separately designed wellbore tractor specific for both fluid detection and valve manipulation is then deployed to detect and control the injection entry points to create an effective EGS through paired horizontal injectors and open hole producers. The wells will be connected through multiple networks of induced and natural fractures that can be controlled throughout the field life.
Optimizing Wasson ROZ CO2 Flood Pattern Configuration for Capital Efficiency: Case Study of 40-Year Field History
Authors: Gang Tao , Jones Andrew , Painter Kaitlyn , Cestari Nicholas , Nezhad Shahin , Burgos Jorge , Bandyopadhyay Parag , Sahni Vinay 
Published: September 2022

Abstract
The use of CO2 injection to produce oil from the residual oil zone (ROZ) of the Wasson field in the Permian Basin has proven to be highly successful when an appropriate development plan is used. The significant volume of oil in place in the ROZ presents a large target for both reserves addition and CO2 sequestration. More than 60% of the ROZ potential lies beneath the already developed San Andres main oil column (MOC) area, which is under CO2 flooding with varying states of maturity, making it challenging to develop such projects efficiently and economically.
Over the past 20 years, different pattern configurations (nine-spot, line drive, five-spot) and completion strategies (commingled injector, injection subsurface flow control devices, dual completion injection, dedicated and hybrid line drive) have been used at the Wasson oil development company (ODC) field to develop the ROZ. The results of these various pattern configurations and completion techniques and their pros and cons are discussed in this paper. Commingled production makes it more difficult to quantify incremental ROZ production and increases uncertainty in the performance forecast of future ROZ projects. The dedicated injectors provide better injection control to MOC and ROZ and improve CO2 utilization, especially where the MOC is mature.
In this paper, we present one of the key findings from a detailed analysis of field history that caused Oxy to switch from the original dedicated ROZ development to a hybrid line drive pattern configuration. This novel strategy will have higher CO2 retention and more sequestration potential, better areal sweep efficiency for improved oil recovery, and lower capital and operating cost. It also reduces the likelihood of injector interference, provides a stable injection throughput for a long time, and results in a sustained oil and CO2 production plateau, which leads to more efficient utilization of plant capacity.
Using ODC as an example, the total capital, F&D costs, and the number of new injection wells will be reduced by 33%, 35%, and 45%, respectively, for changing all the undeveloped patterns from the dedicated to hybrid line drive option. This novel development strategy improves the chance of promoting contingent resources (not currently considered to be commercially recoverable owing to one or more contingencies) to a higher category and offers higher returns with much lower F&D cost and shorter development time.