bluuebunny/crossref_metadata_2025_split huggingface dataset:
Multisite Evaluation of a Custom Energy-Storing Carbon Fiber Orthosis for Patients with Residual Disability After Lower-Limb Trauma
Authors: Potter Benjamin K. , Sheu Robert G. , Stinner Daniel , Fergason John , Hsu Joseph R. , Kuhn Kevin , Owens Johnny G. , Rivera Jessica , Shawen Scott B. , Wilken Jason M. , DeSanto Jennifer , Huang Yanjie , Scharfstein Daniel O. , MacKenzie Ellen J. ,   on behalf of the METRC PRIORITI-MTF Team
Published: October 2018

Background:
The Intrepid Dynamic Exoskeletal Orthosis (IDEO) is a custom energy-storing carbon fiber ankle-foot orthosis developed for lower-extremity trauma patients. Studies conducted at the military treatment facility where the IDEO was developed demonstrated benefits of the IDEO when used with the Return to Run Physical Therapy (RTR PT) program. The current study was designed to determine if results could be replicated at other military treatment facilities and to examine whether early performance gains in patient-reported functional outcomes remained at 12 months.

Methods:
Study participants included service members who had functional deficits that interfered with daily activities at least 1 year after a traumatic unilateral lower-extremity injury at or below the knee. Participants were evaluated before receiving the IDEO, immediately following completion of RTR PT, and at 6 and 12 months. Agility, strength/power, and speed were assessed using well-established performance tests. Self-reported function was measured using the Short Musculoskeletal Function Assessment (SMFA). The Orthotics and Prosthetics Users’ Survey was administered to assess satisfaction with the IDEO. Of 87 participants with complete baseline data, 6 did not complete any physical therapy and were excluded from the analysis. Follow-up rates immediately following completion of the RTR PT and at 6 and 12 months were 88%, 75%, and 79%, respectively.

Results:
Compared with baseline, improvement at completion of RTR PT was observed in all but 1 performance test. SMFA scores for all domains except hand and arm function were lower (improved function) at 6 and 12 months. Satisfaction with the IDEO was high following completion of RTR PT, with some attenuation at the time of follow-up.

Conclusions:
This study adds to the evidence supporting the efficacy of the IDEO coupled with RTR PT. However, despite improvement in both performance and self-reported functioning, deficits persist compared with population norms.

Level of Evidence:
Therapeutic Level IV. See Instructions for Authors for a complete description of levels of evidence.
A Coal Seam Gas Development Evaluation Workflow
Authors: Kuznetsov Dan , Van Spaendonck Rutger , Beaney Simon 
Published: October 2018

Abstract
In this paper we present an example of a Coal Seam Gas field evaluation that funnels multiple realisations of the subsurface forecast for different well spacing into a simple visual tool for economic screening of the development opportunities.
The evaluation approach can be described as follows: consolidate the available data in a regional scale geological model; identify the prospective production seams and areas based on a combination of static properties; automatically populate the potential development areas with model wells of different types, completions and lateral spacing; and run the resulting multiple reservoir models in a dynamic simulator. Finally economic metrics, e.g. average gas produced per well, unit cost, or NPV, are applied to the predicted production, and the development options are compared when the metrics are plotted against the total produced gas or well count.
Application of the workflow to an actual project evaluation demonstrated its robustness for the decision making process. The area of interest is about 100 km2 and contains several coal seams, which are proposed to be developed using surface to inseam, horizontal wells. Several well layouts with different spacing between lateral wells were evaluated using multiple subsurface realisations. Proposed wells in each development option were sorted by their median (P50) of predicted produced gas volume and their economic metrics plotted against the total produced gas. If the best wells are drilled first, the economic value of the project starts eroding after a certain number of wells are drilled. This happens because each new well delivers less gas while the cost of the well doesn't reduce at the same rate. The sweet spot is being exhausted. The cloud of well metrics as a function of the number of wells drilled or total gas produced provides an efficient tool for evaluating the optimal size of the project and its economic feasibility.
Due to relatively low permeability of the coal cleat system and large area of interest, the static model had to be split spatially and by seams with the model grid being refined for dynamic simulation. Automation of this workflow made it possible to evaluate multiple development options with multiple subsurface realisations within a tight project timeframe.
The workflow provides a structured framework for selecting economically feasible development options based on the pre-defined criteria while taking into account the subsurface complexity and uncertainty.
Sucker Rod Anti-Buckling System to Enable Cost-Effective Oil Production
Authors: Clemens Langbauer , Rudolf Fruhwirth , Manuel Hartl , Herbert Hofstätter 
Published: October 2018

Abstract
In days where the oil price is low, cost optimization is of vital importance. Especially in mature oil fields, the reduction of lifting costs by increasing the mean time between failure and the overall efficiency helps to stay economical and increase the final recovery factor. Today a significant portion of artificially lifted wells use sucker rod pumping systems. Although its efficiency is in the upper range, compared to other artificial lift systems, there is room for improvement and system optimization.
This paper presents the benefits of the field-tested Sucker Rod Anti-Buckling System (SRABS), which can entirely prevent compressive loads from the sucker rod string by a redesign of the standing valve, the advantageous use of the dynamic liquid level, and the on a case-by-case basis application of a tension mass. This results in complete buckling prevention and a reduction of the overall stress in the sucker rod string.
The resulting reduction in the number of well interventions in combination with the higher overall pumping efficiency prolongs economic production in mature oil fields, even in times of low oil prices. The analysis of SRABS, using simulations, showed a significant increase in the overall efficiency. The SRABS performance and wear tests under large-scale conditions are performed at the Montanuniversitaet Leoben's Pump Testing Facility and in the field. The self-developed Pump Testing Facility can simulate the conditions of a 500 m deep well, including the effects of dynamic liquid pressure and temperature. Testing of SRABS has identified major benefits in comparison to standard sucker rod pumps.
The results of intensive testing are used to optimize the geometry of the pump body itself and to improve the wear resistance by selecting optimal materials for the individual pump components. SRABS itself can be applied within every sucker rod pumping system; the installation is as convenient as for a standard pump, and manufacturing costs are comparable with those of a standard pump. This paper shows the high performance of the SRABS pumping system in comparison to a standard sucker rod pump.
Depleted Drilling System: Use of Aerated Mud in Surat CSG Wells
Authors: Bhavnani Pankaj , Richards Dylan 
Published: October 2018

Abstract
The operator's strategy is to maximise economic upstream gas production by drilling technically-mature sustaining wells in depleted areas of Surat basin in Queensland, Australia. To date the operator has drilled more than 2800 Coal seam gas wells with minimal well control issues.
Historically wells drilled in Surat basin were normally pressured vertical wells with depths ranging from 600-1000m TVD. The wells are drilled with water + KCL (weighting agent) with mud weight in range of 8-6-9 ppg. However, few wells drilled in late 2016/17 in Central Surat area showed signs of significant depletion in terms of drilling fluid losses and multiple well control events which suggested that prolonged production from these coal seams have reduced the reservoir pressure & correspondingly fracture gradient. Those wells were controlled with conventional well control methods. But this had an impact on the well duration and the wells were drilled at considerable cost. This prompted the Well Engineering team to look for alternative mud systems which can reduce the losses to coals and any reservoir productivity impact.
This paper represents the well planning and design process undertaken to drill these depleted wells with a Near balanced fluid system – Aerated mud (a combination of water and air). The author also has included operational results from four trial coal seam gas wells drilled with Aerated mud. The objective of the trial was to understand the impact of drilling the depleted coal seams with lighter fluid and any time/cost impact.
Porosity Determination via Contrast Enhanced Micro CT Scanning and Digital Core Analysis: A Case Study of X Field
Authors: Sazali Wan Muhammad , Md Shah Sahriza Salwani , Kashim M Zuhaili , Kantaatmadja Budi Priyatna , Knuefing Lydia , Young Benjamin , Goodwin Carley 
Published: October 2018

Abstract
There are a number of additional challenges in the development of high CO2 content gas fields. To meet the requirements of the Kyoto Protocol and Paris Agreement, an efficient means to deal with the produced CO2 such as re-injection into the reservoir for sequestration is required. With the intention of developing such high CO2 gas fields, PETRONAS has identified a trial candidate (X field) offshore Sarawak Malaysia, which is a carbonate gas field with 70% CO2 content and good potential to re-inject the produced CO2 into the field's aquifer zone. To study the feasibility of CO2 reinjection, PETRONAS R&D team are studying the effects of re-injected CO2 on the mineralogical and petrophysical properties of the reservoir and decided to incorporate Digital Core Analysis (DCA) into the case study. Although porosity determination and other petrophysical property characterisation using micro-CT images has been widely used for a number of years, there is still discussion about its accuracy and reliability. Based on previous internal studies, porosity determination via digital core analysis can be limited by the quality and resolution of micro-CT images collected and thus the capability of the image analysis software. This case study investigates accuracy and reliability of the use of contrast enhanced imaging practices and the use of the helical micro CT for porosity determination via Digital Core Analysis (DCA). PETRONAS adopted and optimized a contrast enhanced imaging methodology for use on 1-inch core plugs during scanning via a helical micro-CT and applied this as a case study to X field with the help of a technology partner to evaluated digital core analysis. In the same year, a commercially available image analysis software was launched, with such a DCA workflow in mind. Using this optimized methodology and the newly launched imaging software, the porosity values from DCA of the 1-inch core plugs show good correlation to the values from Routine Core Analysis (RCA) done on the same samples, with less than 1.5 porosity unit difference. In this case study, PETRONAS managed to compare the porosity obtained from DCA directly with porosity measured by RCA. This methodology will be used for porosity determination for wells or other regions of interest where limited samples or different sample sizes are not suitable for RCA.
Axial Oscillation Tool Combined with Optimized Bent Motor BHA's Successfully Drills Record 3D Horizontal Granitic Basement Section in Vietnam
Authors: Bui Son , Ngo Hai , Nguyen Nam , Blackwell Geoff , Trethewey Jake 
Published: October 2018

Abstract
One of the most challenging drilling applications in Vietnam is granitic basement drilling, where the formation is very hard (35-40Kpsi UCS), not drillable with polycrystalline diamond compact (PDC) cutters, and high vibration levels are experienced. There are many common issues and risks, but despite the challenges, Thang Long Joint Operating Company planned to drill a 3217m 3D horizontal granite section hitting all three targets: building inclination from 20 degrees to 85.6 degrees, holding the lateral, and turning from 62°to 14.3°azimuth, total depth (TD) at 6280m measured depth (MD).
A scientific approach using torque and drag modelling, relevant offset data, and an axial oscillation tool (AOT) to prove drilling to TD is achievable within the acceptable cost and time frame was proposed. A torque and drag model was built from the longest extended reach drilling (ERD) basement section drilled in 2014 (Well X, a 2D well, TD at 7300m MD, 3035m basement section) to understand drilling conditions and limitations. The results were applied in the torque and drag model of the subject well (Well Y). Bent motor bottom hole assemblies (BHAs) were then designed and optimized to minimize string buckling. The modelling was run again, and axial oscillation tools were placed in appropriate zones of each BHA.
The first eight BHAs from the beginning of the granite section at 3063m MD to 5071m MD (completed the horizontal turn at 4313m MD, then held tangent) performed well and stayed close to the planned trajectory. The torque and drag model was continuously updated after each run to predict and prepare the BHA for the next run. From 5071m MD to TD at 6280m MD, optimized bent motor BHAs in combination with two axial oscillation tools were utilized to achieve the directional drilling plan and hit all targets. Two rotary steerable system (RSS) BHAs were used to test an alternative steering solution in granite basement. Both BHAs were unsuccessful in holding the well angle, and repeatedly failed to correct the well path.
The use of axial oscillation technology provides a solution to drilling the granitic basement in Vietnam, which has proven to save operators time and reduce costs, as well as facilitate a more complex and longer basement section to connect multiple pay zones to be planned in the future.
Fracturing with Pure Liquid CO2: A Case Study
Authors: Meng Siwei , Yang Qinghai , Chen Shi , Duan Yongwei 
Published: October 2018

Abstract
After three years of technological breakthrough and field practices, a complete set of patented waterless fracturing operation technology and supporting equipment with independent intellectual property rights have been invented. Obvious oil production increase effect has been observed in multiple field tests on tight sandstone oil reservoir. In this paper, the latest development of Chinese liquid CO2 fracturing technique is introduced through a case study of typical well.
The target depth of operating well is 1730.8m-1757m, with a daily fluid production of 1.6t and oil production of 0.5t, indicating that the displacement relationship has not been effectively established. The fracturing treatment was carried out using the independently developed equipment system, which has treatment capability of available pump rates up to 12 m3/min, sand transportation of 27 m3 and CO2 injection of 1000 m3. During this operation, 860m3 liquid CO2 was injected at a displacement of 5-6m3/min. and 23m3 proppant was preloaded and totally pumped into reservoirs with maximum instantaneous proppant concentration of 12%.
After the fracturing, the daily fluid production increased from 1.9t to 3.9t, the daily oil production increased from 0.7t to 2.3t and the water cut decreased from 63.2% to 41.0%, achieving a significant increase in production. In addition, the oil pressure of one adjacent well increased from 0.5Mpa to 12.4Mpa and the daily oil production of four adjacent wells increased by 0.7-1.1t through the energy enhancement and miscibility of CO2.
The field test shows that liquid CO2 fracturing technology has a significant effects of energy storage and stimulation, adjusts the injection-production relationship effectively, and greatly enhances the single well production. It is expected to become the key technology of the development of tight sandstone oil resources.
Ground Breaking Technology in Artificial Lift; 1st Installation of Full Digital Intelligent Artificial Lift DIAL System at DL field, Brownfield Offshore Malaysia
Authors: Ismail Syahezat , Sy Rahim Sy Puteh , Yahia Zaidil , Elshourbagi Saied Mustafa , Ishak M Faizatulizuddin , Roslan M Rizwan , Che Hamat W Afiq , Ben Amara Abdel , Faux Stephen , Makin Graham 
Published: October 2018

Abstract

Objectives/Scope
Moving to digitalization era in the current low oil price environment, paradigm shift is really crucial in managing brownfield development and production. The challenge is to select the best technology to harvest the optimum production from the field but at the same time reduce potential capital and operating expenditure.

Methods, Procedures, Process
The paper highlights the technology evaluation of Digital Intelligent Artificial Lift (DIAL) system. This includes it's working principles, candidates screening, risk mitigation plan as well as technology success criteria developed specifically for the technology.
DIAL system is an in-well gas lift system that can overcome the well design and operational limitations of existing side pocket mandrels and valves. DIAL enables a better gas lift well design as well as able to interconnect downhole and surface monitoring & control in real-time. It provides opportunity for automation, better subsurface and surface integration as well as minimizing well intervention requirement.
Based on the promising technology evaluation, one pilot well was identified by the team at DL field. The well was part of DL drilling campaign executed in Q2 2018. Details of the well design & scope, as well as gas lift design for the well will be shared. Commercial comparison was demonstrated between conventional side pocket mandrel system and the DIAL system.

Results, Observations, Conclusions
The case study at DL field will be discussed in details, starts from their wells’ design, technology deployment strategy, installation, production test result as well as lessons learnt during installation and operationalization of the system.
Moving forward from the pilot application, root cause failure analysis was done, lessons learnt were identified, design improvements were proposed and continuous monitoring of the system will be done, according to the success criteria outlined. Potential replication candidates have also been identified by the team with at least 10 promising potential candidates to be installed within the next 2 years.

Novel/Additive Information
The technology deployment was the result of collaborative works between PETRONAS, Silverwell Energy and Neural Oilfield Service.
Research of Non-Stop Intermittent Pumping Production for Beam Pumping Units
Authors: Gong Hongliang , Sun Yanan , Zhang Shujin , Qi Xing , Shi Guochen , Sun Chunlong , Wang Guoqing , Zhang Deshi , Wei Feng , Yu Hou , Qing Changrui , Zheng Guoxing , Zhao Yulong , Gao Yang 
Published: October 2018

Abstract
A new technology of the non-stop intermittent pumping production for beam pumping units has been widely used in PetroChina Daqing oil field. This technology solves the problems that existed in conventional intermittent pumping production, such as a large fluctuation in fluid level, a long idle time, high labor intensity, frozen wellhead in winter, and difficulty in management, etc.
This technology adopts a new strategy. It transforms a long-period intermittent pumping into several short-period intermittent pumping, and changes the crank from shutdown into low-energy swinging motion, at the same time, the plunger piston at downhole is kept stationary while the crank does do non-stop swing operation. Based on the maximum elastic deformation of sucker rods, the optimal swing range and rotary speed of crank are designed by kinematics and load analysis. Meanwhile, the inverter increases the swinging amplitude of crank to build up the gravitational potential energy. With conversion effects from gravitational potential energy to kinetic energy, as well as active control of swing power, a non-impact low energy swinging scheme is formed. The flexible switch between complete-cycle pumping operation and swing operation is successfully realized. According to the situation of a single well, the corresponding working system is formulated.
A total of 124 wells had been used this new technology in petroChina Daqing oil field, the filed application shows that, the non-stop intermittent pumping production stabilizes the fluid level within a reasonable range and guarantees a better pump fillage. Compared with the conventional intermittent pumping prodution, the pump efficiency improved 6.54%, the average energy-saving rate ran up to 34.59%. It is significantly improved the pump efficiency and system efficiency, and achieved the purpose of energy saving. The technology of the non-stop intermittent pumping production for beam pumping units is appropriate for the low-yield well and insufficient liquid well. It will be of great significance for the high-efficiency development of low-yield well.