bluuebunny/crossref_metadata_2025_split huggingface dataset:
Technology Trial Review: Selective Coiled Tubing Re-Entry of Seven-Lateral Openhole Well Using Electromechanical Arm
Authors: Abdelaziz Mohannad , Ahmad Talha , Saeed Abubaker , Zarea Marwan , Busfar Wessam , Sagr Hani 
Published: September 2016

Abstract
The number of MRC (Maximum Reservoir Contact) wells has increased significantly since they were first introduced in 2002. Most of these wells use multilateral well configuration to increase the contact with the reservoir and therefore the well productivity. (Salam Phillip Salamy, 2007)
One of the main challenges for multilateral wells is the selective accessibility of the well during the production phase to perform various rig-less activities (such as stimulation, production logging, water shut-off… etc.). This requires detection and confirmation of lateral window depth and orientation and means to allow the tool to be selectively steered into the desired lateral.
From all multilateral well configurations classified by TAML (Technology Advancement of Multi-Laterals), Level-1 (openhole mainbore and lateral) is considered the most difficult to re-enter. This is caused by the fact that the shape and quality of the wellbore near the junction is highly unpredictable after the early lateral window construction and the later distortion by the flow of hydrocarbons. Since both the mainbore and laterals are openhole, the simple metal dependent logging tools (such as CCL: casing collar locator) cannot be used as a way to confirm the successful entry of the openhole lateral as in Level-2 TAML (cased mainbore).
Well Lateral Intervention Tool has been jointly developed to address this issue. The tool has two main sensory packages (ultrasound and magnetic) to obtain the lateral details (depth and orientation) and an electromechanical arm that can be actuated with different angles to guide the BHA inside the required lateral. This paper presents the challenges and outcomes of the tool field trial in a Level-1 multilateral well. The oil producer candidate has an openhole mainbore and six openhole laterals branching from it (fishbone well). The tool has been successfully used to guide PLT (Production Logging Tool) into three of the six laterals limited only by Coiled Tubing reach.
Successful Managed Pressure Cementing With Hydraulic Simulations Verification in a Narrow Pore-Frac Pressure Window Using Managed Pressure Drilling in Saudi Arabia
Authors: Siddiqi Faizan Ahmed , Riskiawan Arris , Al-Yami Abdullah , Elmarsafawi Youssef , Jain Bipin , Louati Issam , Martanto Roni , Taoutaou Salim 
Published: September 2016

Abstract
Managed pressure operations enable keeping the equivalent circulation density (ECD) within a narrow pore-frac pressure window during drilling and cementing while maintaining the wellbore stability and controlling formation pressures. The operation becomes more complex during a cementing job, where fluids with different density and rheology parameters are pumped downhole at varying rates, resulting in different friction pressure profiles. Proper numerical simulators must be used to model such variations and keep the downhole pressure between the pore and fracture pressures during the operation.
Managed pressure techniques and technology were critical to the successful cementation of the 7-in. liner at 12,000 ft. in a gas field in Saudi Arabia, across formations ranging from a high-pressure zone with 2.36 SG (19.65 ppg) formation pore pressure to a depleted low-pressure formation with 2.44 SG (20.32 ppg) fracture pressure. The challenge in this job was to maintain the ECD at 2.40 SG (20 ppg) throughout the cement job to avoid any losses or flow from the formations.
An automatic choke setup on the return flow line with a dynamic control system was used to drill the 8.375-in. open hole with KCl polymer mud. Precise cementing simulation was used to determine the ECD during cement placement. Numerous pre-calculations and simulations were run to evaluate various scenarios prior to the cement job to ensure effective manipulation of back pressure through managed pressure drilling (MPD) equipment to maintain ECD at the desired value throughout the cementation process.
The detailed simulations run by cementing and MPD engineers prior to the job and a collaborative approach were instrumental in defining a final cementing plan, completing the layout of equipment used for the cementing job, and executing the job with real-time monitoring of all critical parameters affecting ECD and evaluation of the cement job.
Computer Modeling for Intelligent Control of Gas-Condensate Reservoir
Authors: Mikolajczak Edyta 
Published: September 2016

Abstract
Smart wells combine monitoring and control technology. These smart completions are equipped with sensors to monitor well and reservoir conditions, and valves to control the inflow of fluids from the reservoir to the well. However, this intelligent equipment is located only in the downhole.
The idea of this paper is to create virtual sensors located in different parts of the reservoir, which will be used to intelligent production control. This work explores a new algorithm for smart control of the gas-condensate reservoir. The proposed algorithm uses the analogies to a greedy algorithm as well as known natural intelligent structures like biological systems. The aim of this paper is to find an optimal well management strategy over the assumed life of reservoir.
Gas-condensate reservoirs have a reservoir temperature located between the critical point and the cricondentherm on the reservoir fluid's pressure-temperature diagram. If bottomhole flowing pressure is less than dew point pressure, then vapour and liquid phases drop out in the porous media around the production well restricting the flow of gas. The near-well chocking can reduce the productivity of a well.
Moreover, one of the goals of this paper is developing intelligent production scenarios for gas-condensate reservoir. The computer simulation has been carried out in the ECLIPSE reservoir simulator and the virtual sensors have been located within the reservoir. The actions programmed according to virtual sensors measurements yield self-modifying strategy of reservoir control. The proposed algorithm analyses reservoir behavior and changes production strategy in each time step to control the condensate bank range and, as a result maximizes the net present value (NPV).
This paper presents a brief description of the created reservoir model and detailed explanation of the proposed algorithm. The next part focuses on the obtained results which indicate that this algorithm ensures intelligent control of gas-condensate reservoir and therefore the most profitable production scenario.
Unconventional Reservoir Perforating Cluster Spacing Optimization Method for Staged-Fracturing Horizontal Well
Authors: Lu Qianli 
Published: September 2016

Abstract
Multi-cluster staged fracturing is an effective method to exploit shale gas. Field observations reported some clusters did not generate fractures. X5 formation in Sichuan Basin is a 3000m deep shale reservoir. The horizontal stress difference is so high, therefore it is difficult to generate fracture network. How to enable all fractures propagate effectively from each cluster and generate enough stress interference to enable fracture network is of critical concern.
This paper established a 3D fracture propagation model based on finite-element method to simulate multi-cluster fracturing of X5 reservoir. The fracture propagation model couples seepage-stress-damage theories to simulate fracture propagation. The cohesive element is used to simulate the forming of fracture, and the filtration from fracture to matrix is taken into consideration. This model is used to study three fractures propagating simultaneously from three clusters. Six different cluster spacing cases were simulated to investigate the fracture geometry and the stress field.
The research finds that when the cluster spacing is 10m, 20m, 30m and 35m, the length of the middle fracture is severely restricted; but for the side fractures, the length is over propagated. When the cluster spacing is 40m and 50m, balanced propagation of all the three fractures is achieved. In the 10m, 20m, 30m, 35m and 40m cluster spacing cases, the horizontal stress ratio is low and could generate fracture network, but the 50m case could not. By considering the fracture geometry and stress ratio, the optimized cluster spacing is 35m-40m. Based on this optimization, a 7-stage fracturing treatment of X55 well was designed and conducted. The treatment process was smooth and its production was 1.7 times the average production of the adjacent horizontal wells.
This paper presented a method to optimize the cluster spacing by both considering the fracture geometry and stress ratio. Cluster spacing optimized by this method could enable the effective propagation of all main fractures and increase the possibility of generating fracture network.
Advanced Production Data Analysis in Oil Carbonate Reservoirs
Authors: Adrian P. M. 
Published: September 2016

Abstract
In recent years there has been an increasing interest in the use of Advanced Production Data Analysis (APDA) methods for dynamic reservoir description. These methods analyze available daily production data, reducing Well Testing operations cost and avoiding production loss, with accuracy comparable to Pressure Transient Analysis (PTA). Different models have been proposed for homogeneous, coalbed methane and shale gas reservoirs. Unfortunately, carbonate reservoirs production are still being analyzed with homogeneous models.
This work presents the analytical derivation of two Advanced Production Data Analysis methods (Dynamic Material Balance and Blasingame Type Curves) based on the dual porosity model, to analyze daily production of Oil Carbonate reservoirs. Pseudosteady-state and transient (slabs and spheres) interporosity flow between matrix and fractures were considered.
The development was based on long-time approximate solutions of diffusivity equation in dual porosity system, for constant flow rate in a closed system with no-flow boundary. They were compared to exact solution in Laplace Space using Gaver-Stehfest algorithm. Then applying the appropriate dimensionless definition, both APDA methods were derived, including the generation of type curves. The validation was made using synthetic data generated by a numerical simulator for constant and variable flow rate.
Results confirm the applicability of current APDA methods basd on homogeneous reservoirs, for the cases of transient interporosity flow between matrix and fracture. Nevertheless, additional considerations must be taken into account in the case of pseudosteady-state interporosity flow.
Development of Centrifugal Downhole Oil/Water Separator: Simulation and Experimental Study
Authors: Hashem Mohamed Hossni 
Published: September 2016

Abstract
In the shadow of low oil prices, it is necessary to develop economically and environmentally friendly solutions. In oil and gas industry, majority of the production stream is water. This water is produced with the hydrocarbon to surface. This requires the separation of the fluids produced and then treating those streams to abide with environmental regulations and clients' specifications. CDOWS (Centrifugal Downhole Oil Water Separator) technology is believed to provide high separation quality, high oil recovery with reduction of operating costs and less surface facilities.
The development process involves simulation of tubular centrifuge using a computational fluid dynamics (CFD) software to analyze the parameters affecting separation. After that, an experimental set up is erected which mimics in-well CDOWS. The novel design of the tool involves specially designed weir to collect the oil and water through concentric tube configuration. The parameters tested through simulation include; flow rate, RPM, tubing length, tubing diameter, API and oil/water ratios. The experimental set-up is used to confirm the sepration in the rotating tube as it is made of acrylic material.
The CFD model involves a rotating cylinder (tubing) in which oil and water are introduced from the inlet. The feed of oil and water exhibits high centrifugal forces resulting in their separation through and to the outlet of the tubing. The experimental design mimics the actual in-well design which can be implemented in a well. The design can be configured easily to change the tubing parameters.
After conducting the studies, a sensitivity analysis using design of experiment approach (DOE) and response surface plots is produced to emphasize on parameters and their interaction effects.
Findings include better separation using higher RPM, ID, L, water salinity, API. The most influential factor is RPM which can be controlled and thus will define costs for later stages of the project.
This paper presents the first work on CDOWS which is analogous to in-well configuration aiming for a solution with reduced costs.
Reducing Freshwater Consumption in the Marcellus Shale Play by Recycling Flowback With Acid Mine Drainage
Authors: Cavazza Michael 
Published: September 2016

Abstract
Acid mine drainage (AMD), the largest source of stream pollution in the state of Pennsylvania, has the potential to be utilized as a make-up fluid for hydraulic fracturing in the Marcellus shale. Abandoned coal mines across the state are responsible for discharging AMD into nearby streams, imairing local ecosystems. If AMD could be used in hydraulic fracturing operations, gas companies can be responsible for a cleaner environment in Pennsylvania. To use AMD in hydraulic fracturing, the high sulfate (SO42-) concentration must be reduced (&lt;100 mg/L). If not, there is a risk of scale formation in the wellbore.
Sulfate concentrations can be reduced by mixing AMD with flowback, which has high concentrations of barium (Ba2+) and strontium (Sr2+). Sulfate will react with the barium and strontium to precipitate barite (BaSO4) and celestite (SrSO4) which can be removed from the fluid. The challenge is determining mix ratios of the two fluids, AMD and flowback, to reduce these three constituents to acceptable levels. Both AMD discharges and flowback vary from location to location making this challenge a difficult one.
For this study four coal mine discharges and two wells located in southwestern Pennsylvania were sampled. These samples were mixed at various ratios to determine removal efficiencies and kinetics for sulfate, barium and strontium precipitation. Ideally, these reactions would occur quickly and result in a fluid free of sulfate, barium and strontium. The mixing tests showed that barium and sulfate could be removed to acceptable levels, while strontium could only be removed by a maximum of 50%. X-ray diffraction (XRD) analysis concluded that celestite does not form when the fluids are mixed, rather strontium co-precipitates with barium. Kinetic tests showed that precipitation reactions occur quickly, within one day of mixing and no further reactions occurred.
Simulation Opportunity Index, A Simple and Effective Method to Boost the Hydrocarbon Recovery
Authors: Saputra Wardana 
Published: September 2016

Abstract
During periods of low oil prices, profitability of field developments drops drastically. To help with this difficulty, a cost-effective method has been proposed to boost the hydrocarbon recovery by optimizing well locations through the Simulated Opportunity Index (SOI). SOI is an intelligent method to identify zones with high potential for production which is empirically calculated from basic rock and fluid properties, and from reservoir pressure as its energy capacity. In order to obtain the best results, the original SOI formula (Molina et al., 2009) was extended to both oil and gas fields. Based on this modified SOI formula, a software program has been developed to locate the best well locations considering multilayer, existing wells, and fault existences.
This paper describes how the SOI software helps as a simple, fast, and accurate way to obtain the higher hydrocarbon production than that of trial-error method and previous studies in two different fields located in offshore Indonesia. On one hand, the proposed method could save money by minimizing the required number of wells. On the other hand, it could maximize profit by maximizing recovery.
Wave Propagation Models Capture Pressure Behavior in Heterogeneous Unconventional Reservoirs
Authors: Li Hanyu 
Published: September 2016

Abstract
Estimating ultimate recovery using information from the boundary-dominated flow regime is not practically achievable in unconventional (low permeability) resources since the time required to reach this flow regime is quite large (typically years). In response to this problem, the ultimate objective of this research project is to estimate ultimate recovery of horizontal wells with multistage fractures using only information obtained after wells have reached interference between adjacent fractures. I have taken the first step towards achieving this objective by simulating the boundary condition in heterogeneous reservoirs using the similarity between pressure diffusion and electromagnetic and ray wave propagation. Estimating ultimate recovery more accurately will enable us to optimize well spacing and reduce the number of unnecessary wells drilled, saving capital investments of many millions of dollars.
I have implemented the mechanism of electromagnetic and ray wave propagation in pressure diffusion models to simulate boundary conditions that affect flow in the reservoir. When a light wave reaches the interface of two media, some light is reflected back to the same media while the remainder is transmitted into the other media. A ‘pressure wave’ behaves in a similar way when it reaches a boundary in the reservoir. Therefore, we have incorporated reflection and transmission coefficients into the drawdown solution of the diffusivity equation. We used a channel reservoir to validate our approach. The pressure transient analysis solution obtained using our method matches well with the true solution generated by the pressure transient software Ecrin. We can use the accurate early time match to estimate important reservoir properties including porosity and permeability. The accurate middle time pressure information can be transformed into rate information and then used to estimate ultimate recovery.
Exploring Climate‐Smart Land Management for Atlantic Europe
Authors: Schulte Rogier P. O. , O’Sullivan Lilian , Coyle Cait , Farrelly Niall , Gutzler Carsten , Lanigan Gary , Torres‐Sallan Gemma , Creamer Rachel E. 
Published: September 2016

Core Ideas
Managing soil organic carbon is an essential aspect of climate‐smart agriculture.
Combining component research, we derive a soil carbon management concept for Ireland.
Optimized soil carbon management is differentiated in accordance with soil type.
Existing policy tools can be tailored to incentivize climate‐smart land management.
Soils can be a sink or source of carbon, and managing soil carbon has significant potential to partially offset agricultural greenhouse gas emissions. While European Union (EU) member states have not been permitted to account for this offsetting potential in their efforts to meet the EU 2020 reduction targets, this policy is now changing for the period 2020 to 2030, creating a demand for land management plans aimed at maximizing the offsetting potential of land. In this letter, we derive a framework for climate‐smart land management in the Atlantic climate zone of the EU by combining the results from five component research studies on various aspects of the carbon cycle. We show that the options for proactive management of soil organic carbon differ according to soil type and that a spatially tailored approach to land management will be more effective than blanket policies.
Dissipation of Antimicrobials in a Seasonally Frozen Soil after Beef Cattle Manure Application
Authors: Amarakoon Inoka D. , Surac Srinivas , Zvomuya Francis , Cessna Allan J. , Larney Francis J. , McAllister Tim A. 
Published: September 2016

Land application of manure containing antimicrobials results in the dispersion of the antimicrobials in agro‐ecosystems. Dissipation of excreted antimicrobials in seasonally frozen agricultural soils has not been fully characterized under field conditions. This study investigated the field dissipation kinetics of chlortetracycline, sulfamethazine, and tylosin over a 10‐mo period after fall application of manure from cattle (Bos taurus) administered 44 mg chlortetracycline (chlortetracycline treatment [CTC]), 44 mg each of chlortetracycline and sulfamethazine (CTCSMZ), or 11 mg tylosin per kg feed daily. Antimicrobial concentrations in manured soil reflected the same relative concentrations in manure: chlortetracycline > sulfamethazine > tylosin. The first‐order dissipation half‐life (DT50) for chlortetracycline from the CTCSMZ treatment was 77 d during the growing season and 648 d during the nongrowing season when the soil was frozen for an extended period. By comparison, dissipation of chlortetracycline added alone (treatment CTC) did not differ significantly between the two seasons (mean DT50, 121 d). During the nongrowing season, chlortetracycline from CTC dissipated faster (P = 0.004) than that from the CTCSMZ treatment, indicating that the presence of sulfamethazine may have altered the dissipation of chlortetracycline. Dissipation kinetics for sulfamethazine and tylosin were not determined due to low detection in the manure‐amended soil. Sulfamethazine was detected (up to 16 ± 10 µg kg−1) throughout the 10‐mo monitoring period. Tylosin concentration was ≤11 ± 6.6 µg kg−1 and gradually dissipated. Chlortetracycline was detectable 10 mo after application in the seasonally frozen soil, indicating a risk for residue build‐up in the soil and subsequent offsite contamination.Core Ideas
Manure application can disperse antimicrobials in the environment.
Chlortetracycline dissipation followed first‐order kinetics.
Seasonal effects on chlortetracycline dissipation varied with the source of the antimicrobial.
The presence of sulfamethazine slowed down the dissipation of chlortetracycline.
Concentrations of tylosin and sulfamethazine in manured soil were low.