bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Relationship Between Subluxation Percentage of the Femoroacetabular Joint and Acetabular Width in Asian Women with Developmental Dysplasia of the Hip
Authors: Okuzu Yaichiro , Goto Koji , Kawata Tomotoshi , So Kazutaka , Kuroda Yutaka , Matsuda Shuichi 
Published: April 2017

Background:
Implantation of the acetabular cup insert in the “true” location of the acetabulum is a fundamental principle of total hip arthroplasty for the treatment of secondary osteoarthritis due to developmental dysplasia of the hip (DDH). As knowledge of the morphology of the acetabulum is required for accurate placement, we investigated the relationship between acetabular width and the Crowe classification of subluxation percentage of the hip. We also analyzed factors associated with the acetabular width ratio (AWR), defined as the acetabular width of the dysplastic hip divided by that of the unaffected, contralateral hip.

Methods:
We completed a retrospective review of the preoperative standard anteroposterior radiographs and computed tomography (CT) scans of 207 female patients who underwent primary total hip arthroplasty for unilateral DDH. The “true” acetabular plane was defined on each CT reconstruction as a plane perpendicular to the anterior pelvic plane, parallel to the teardrop line, and passing through the center of the femoral head on the unaffected, contralateral side. The acetabular width was measured for both the affected hip and the contralateral, reference hip on the true acetabular plane, with the acetabular width defined as the distance between the edges of the anterior and posterior walls of the acetabulum. All hips were classified according to the Crowe groupings on the basis of the subluxation percentage of the dysplastic hip; the subluxation percentage increased from groups I to IV, with group IVb showing joint dislocation.

Results:
The acetabular width decreased from Crowe groups I to IVb, with a negative correlation found between the AWR and the subluxation percentage (Spearman correlation coefficient, ρ = −0.404; p < 0.001). Multivariate regression analysis identified subluxation percentage and femoral neck-shaft angle as independent factors associated with the AWR.

Conclusions:
Characterization of factors associated with the AWR, namely subluxation percentage and femoral neck-shaft angle, will guide surgeons in correctly implanting the acetabular cup insert during total hip arthroplasty in patients with DDH.
Ratio of Range of Motion of the Ankle and Surrounding Joints After Total Ankle Replacement
Authors: Dekker Travis J. , Hamid Kamran S. , Easley Mark E. , DeOrio James K. , Nunley James A. , Adams Samuel B. 
Published: April 2017

Background:
This study attempted to identify where motion occurs after total ankle replacement, the difference in range-of-motion contributions between fixed-bearing and mobile-bearing total ankle replacements, and the contribution of abnormal peritalar motion. We hypothesized that sagittal plane radiographic assessment would demonstrate that actual ankle motion through the prosthesis is less than the total arc of ankle motion that may be observed clinically secondary to contributions from adjacent joints.

Methods:
Patients underwent routine standardized weight-bearing maximum dorsiflexion and plantar flexion sagittal radiographs. Sagittal plane ankle and foot measurements were performed on each dorsiflexion and plantar flexion radiograph to determine the total arc of ankle motion, actual ankle motion through the prosthesis, motion through the subtalar and talonavicular joints, and midfoot motion. Motion radiographs were routinely made at 1 year postoperatively and at the time of the most recent follow-up. A minimum follow-up of 2 years was required of all patients.

Results:
There were 197 patients who met the inclusion criteria (75 INBONE, 52 Salto Talaris, and 70 STAR prostheses). The mean time to the latest radiographs (and standard deviation) was 42.9 ± 18.8 months. The mean actual ankle motion through the prosthesis was 25.9° ± 12.2°, which was significantly less (p < 0.001) than the mean total motion arc of 37.6° ± 12.0°. The motion of the ankle accounted for 68% of total range of motion, and motion of the peritalar joints accounted for 32%. There was no significant difference (p > 0.05) among the 3 prostheses or when comparing fixed and mobile-bearing designs for both ranges of motion.

Conclusions:
This study demonstrates that actual ankle motion after total ankle replacement is approximately 12° less than the total arc of motion that might be observed clinically because of increased midfoot and subtalar motion.

Level of Evidence:
Therapeutic Level IV. See Instructions for Authors for a complete description of levels of evidence.
Minimally Invasive Osteosynthesis with a Bridge Plate Versus a Functional Brace for Humeral Shaft Fractures
Authors: Matsunaga Fabio Teruo , Tamaoki Marcel Jun Sugawara , Matsumoto Marcelo Hide , Netto Nicola Archetti , Faloppa Flavio , Belloti Joao Carlos 
Published: April 2017

Background:
Nonoperative treatment has historically been considered the standard for fractures of the shaft of the humerus. Minimally invasive bridge-plate osteosynthesis for isolated humeral shaft fractures has been proven to be a safe technique, with good and reproducible results. This study was designed to compare clinical and radiographic outcomes between patients who had been treated with bridge plate osteosynthesis and those who had been managed nonoperatively with a functional brace.

Methods:
A prospective randomized trial was designed and included 110 patients allocated to 1 of 2 groups: surgery with a bridge plate or nonoperative treatment with a functional brace. The primary outcome was the Disabilities of the Arm, Shoulder and Hand (DASH) score at 6 months. The score on the Short Form-36 (SF-36) life-quality questionnaire, complications of treatment, Constant-Murley score for the shoulder, pain level, and radiographic results were assessed as secondary outcomes. Participants were assessed at 2 weeks; 1, 2, and 6 months; and 1 year after the interventions.

Results:
The mean DASH score of the bridge plate group was statistically superior to that of the functional brace group (mean scores, 10.9 and 16.9, respectively; p = 0.046) only at 6 months. The bridge plate group also had a significantly more favorable nonunion rate (0% versus 15%) and less mean residual angular displacement seen on the anteroposterior radiograph (2.0° versus 10.5°) (both p < 0.05). No difference between the groups was detected with regard to the SF-36 score, pain level, Constant-Murley score, or angular displacement seen on the lateral radiograph.

Conclusions:
This trial demonstrates that, compared with functional bracing, surgical treatment with a bridge plate has a statistically significant advantage, of uncertain clinical benefit, with respect to self-reported outcome (DASH score) at 6 months, nonunion rate, and residual deformity in the coronal plane as seen on radiographs.

Level of Evidence:
Therapeutic Level I. See Instructions for Authors for a complete description of levels of evidence.
Testing Tiny Grains Seeking More Output
Authors: Rassenfoss Stephen 
Published: April 2017

The challenge of selling microproppant was obvious when the first question asked after a recent presentation was: “I thought 100 mesh [fine proppant] was dust. So what is microproppant?”
Rather than repeat the explanation in his talk, the speaker James Calvin, a technical sales advisor at Halliburton, responded, “It is even finer.”
The exchange drew a laugh from the audience at this year’s SPE Hydraulic Fracturing Technology Conference and Exhibition in January, which had heard him explain that proppant that is a fraction of the size of the smallest now used—about 300 mesh—may be able to significantly increase production by holding open fractures that cannot be reached by widely used grains of sand or ceramic.
The question suggests that it is still hard for experts in this field to conceive of how particles whose size is typically measured in microns could offer meaningful benefits. And even among those who see value, there are conflicting theories about what it does in the ground.
At this stage the only company reporting results is Halliburton, which pumps microproppant as part of its MicroScout service. “Field results for MicroScout have shown a positive uplift of production in most of the wells that we have field trialed,” said Philip Nguyen, the chief technical advisor for Halliburton’s production enhancement line. “To be frank, there are lots of unknowns with the application of microproppant as we are only beginning to scratch the surface of using this material in shales.”
That paper (SPE 184863) and others from Halliburton dating back to 2015 offer examples of wells with double-digit production gains when a relatively small volume of these particles are pumped early in each stage, and can reduce the treating pressure required while pumping a job.
“We have seen about a 15% uplift in production over 12-month time frame,” said Mark Parker, technology manager for the Mid-Continent area at Halliburton, which includes the South Central Oklahoma Oil Province (SCOOP) in Oklahoma, where it has been used on nearly 20 wells.
In the Permian Basin, gains have ranged from 15% to 30% where this has been pumped during the early part of each stage. “Theoretically, you are getting secondary fractures [propped] and getting added flow from reservoir to the well,” said Dean Prather, area technology manager for Halliburton’s production enhancement business line.
In a sense this is the logical next step. Over time operators have slowly embraced the idea that using higher percentages of 100-mesh sand to prop early in the job can open smaller fractures and reduce the required pressure needed to treat stages.
Calvin described the production gain by saying: “We placed it in the secondary fracture network and it can go where 100 mesh cannot go. It can keep the secondary fracture network open through production and help minimize the production loss.”
Integrating Social Performance into Management System Towards Achieving Sustainability
Authors: Choon Foo Siang , Rj Musa Rj Tatina 
Published: April 2017

Abstract
Social responsibility is vital for companies to manage social impacts in its areas of operations. Integrating key elements of social responsibility into a management system demonstrates PETRONAS' commitment in managing its social risks and leveraging on opportunities to improve the business.
In PETRONAS, Social Performance is integrated into a management system. It applies the ‘plan’, ‘do’, ‘check’ and ‘act’ (PDCA) cycle towards continual improvement and sustainability of the business. Therefore, Social Performance is a key consideration in business and project decision making. It offers great clarity and guidance to PETRONAS to conduct its business activities as a socially responsible corporate entity.
The focus of this paper is the component of Risk Management. Majority of social risks in PETRONAS are related to human rights which cut across the PETRONAS Social Performance Framework. A robust Social Risk Assessment (SRA) is established by integrating it into a management system. SRA enables projects and businesses to identify risks and impacts, as well as develop and prioritise the appropriate mitigation measures. The paper also discusses other integral elements of Social Performance in a management system.
Social Performance in a management system allows the company to identify and mitigate both actual and potential social risks across projects and facilities lifecycle. Hence, effective mitigation plans can be developed to manage these risks which aim to secure privilege to operate to avoid project delays, cost overrun, and opportunity loss as well as reputation damage. It supports PETRONAS projects to meet requirements for project financing, legislative and voluntary requirements. In addition, PETRONAS is aligning itself to industry's good practices.
In managing social risks, the integration benefits the organisation to improve its performance, productivity, overcoming the barriers to communications, clear accountabilities and reduce cost overruns. It also helps companies to save time, reduce conflicts and ensure performance efficiency and consistency in managing social risks.
Studies on a Hybrid of Movable Gel and ASP Flooding Further EOR for the Reservoir after Polymer Flooding
Authors: Zhu Youyi , Fan Jian , Tian Jing 
Published: April 2017

Abstract
Most of the high permeability reservoirs in Daqing Oilfield have been conducted by water flooding and polymer flooding. 507 million tons geological reserves have entered post-polymer flooding stage. The average recoverable oil recovery has reached to 53.2% after polymer flooding. Currently, the further development of such reservoir has become a big challenge due to both of serious heterogeneity of reservoir and highly dispersed residual oil. The reservoir development has entered into quaternary recovery stage. Most of conventional enhanced oil recovery (EOR) techniques could not achieve the desired effects. A hybrid flooding combine movable gel (MG) with alkali-surfactant-polymer (ASP) flooding, as a candidate further EOR technique integrating both properties of mobility control and oil displacement has been proposed for Daqing reservoir after polymer flooding.
In this study, systematic laboratory experiments on MG formulation, ASP formulation and hybrid of MG/ASP flooding for Daqing reservoirs after polymer flooding have been performed. Several important parameters of the hybrid systems of MG/ASP flooding were investigated and optimized based on formulation selection and core flooding experiments. Further EOR effect of the hybrid flooding on core flooding was evaluated.
The main factors that influences on oil recovery by a hybrid of MG/ASP flooding were described as follows. Firstly, the properties of MG and slug sizes were the key factors to improve the mobility ratio. The MG formulas were optimized with good performance of gel property and indepth profile control property of displacement fluid. Secondly, the properties of ASP formulations and slug sizes play the important roles in oil displacement efficiency. The ASP formulations were developed with ultralow interfacial tension between crude oil and ASP solution. Concentration of chemicals and slug sizes were optimized for high EOR efficiency. Thirdly, a hybrid of MG/ASP flooding was optimized at the reservoirs condition. EOR effect of the hybrid flooding was studied upon three-layer positive rhythm sandpack core flooding experiments. Results indicated that hybrid flooding could contribute to incremental oil recovery of 14.7%-18% (OOIP) even if the recovery after polymer flooding was nearly 53%.
The MG could block preferential flow path of high permeability layer in heterogeneous reservoirs, and avoid the fluid channeling during oil displacement process. On the other hand, ASP flooding also had higher oil displacement efficiency for the relatively low permeability layer. The hybrid of MG/ASP flooding might become a promise alternative further EOR method for Daqing reservoirs after polymer flooding.
Mechanistic Study of Surfactant/Polymer Adsorption and Its Effect on Surface Morphology and Wettability
Authors: Al-Wahaibi Yahya , Al-Hashmi Abdul-Aziz , Joshi Sanket , Mosavat Nader , Rudyk Svetlana , Al-Khamisi Sami , Al-Kharusi Thuraya , Al-Sulaimani Hanaa 
Published: April 2017

Abstract
The need for a better understanding of surfactant/polymer adsorption, its quantification, and its influence on the physiochemical properties of reservoir rock can be crucial in the application and optimization of ASP flooding for EOR. This study is aimed to quantify surfactant/polymer adsorption onto Berea sandstone and reservoir rock. Surfactant and polymer adsorption onto crushed core samples and their consequent influence on surface morphology and wettability alteration were investigated. In addition, the effect of the presence of a pre-adsorbed polymer or surfactant layer on the subsequent surfactant or polymer adsorption was investigated. The chemicals used were a partially hydrolyzed polyacrylamide and an Internal Olefin Sulfonate surfactant. Polymer and surfactant concentrations in solutions were measured using total organic carbon (TOC) analyzer and potentiometric titration, respectively. Crushed core samples were analyzed for clay content and minerals by X-ray powder diffraction (XRD). Contact angle was measured on glass slides that has been incubated in brine, polymer and surfactant solutions for brine/hexadecane and brine/crude-oil systems. Amott tests were performed to quantify the wettability alteration due to brine, polymer and surfactant solutions using reservoir oil and core plugs. Results show that polymer and surfactant adsorption follows Langmuir adsorption isotherms. The polymer adsorbed amount on crushed reservoir core was around 450 mg/100g at the plateau region using the synthetic brine (salinity of 1% and pH of 8). Surfactant adsorption on crushed Berea core and crushed reservoir core at the plateau region were 700 mg/100g and 400 mg/100g, respectively. The higher surfactant adsorption on Berea cores is attributed to its higher clay and calcite content compared to the reservoir core. Contact angle (CA) on glass slides increased against both hexadecane and crude oil after surfactant adsorption onto the glass surface, which indicates that wettability-altering effect of surfactant on the surface to be more oil-wet. However, the CA remained nearly unchanged after polymer adsorption. Glass slides treated with polymer adsorption followed by surfactant adsorption ‘P-S’ and surfactant adsorption followed by polymer adsorption ‘S-P’ changed towards more oil-wet indicating higher influence of surfactant adsorption on wettability alteration. The FESEM images showed different adsorption pattern for surfactant treated slides. The Amott index of original brine/oil system was altered from 0.87 to 0.67 and 0.50 for polymer/oil and surfactant/oil systems, respectively. Hence, surfactant shows a pronounced influence on altering the wettability of the original reservoir rock to be less water-wet.
Application of Heavy Weight Cement-Resin Blend System to Prevent CCA Pressure in Saudi Arabia Deep Gas Fields
Authors: Yami Abdullah , Buwaidi Husain , Al-Herz Ali , Mukherjee Tushar S. , Bedford David , Viso Ramon , Hugentobler Kory 
Published: April 2017

Abstract
Sustained casing pressure, otherwise known as casing-casing annulus (CCA) pressure, is a common problem encountered in the deep, high pressure, high temperature (HPHT) gas fields of Saudi Arabia, and in many other locations globally. Although many solutions have been tried in these fields over the years, none of the existing solutions have proven to be 100% effective. A new solution has recently been implemented in Saudi Arabian gas fields that features a combination of heavy-weight cement blends greater than 21ppg and a polymer resin to improve the mechanical properties of the cement, especially the shear bond, to prevent the CCA pressure. Polymer resin is also resistant to hydrocarbons, acids, and salts, enabling the cement-resin system to be placed in harsh environments. This resistance will help to maintain a dependable barrier throughout the life of the well.
This paper presents a case history of the application of this heavy-weight cement-resin (HWCR) system in the Saudi Arabia Harradh field where the failure of a differential valve (DV)packer meant that there would be no redundancy backup should the cement fail to provide a full barrier in the annulus. The paper describes the process used to design the HWCR system and how its application is critical to the success of the job.
Application of Closed Fracture Acidizing for Stmulation of Tight Carbonate Reservoir in Mumbai Offshore
Authors: Sarma Dilip Kumar , Pal Tej , Kumar Dileep , Lahiri Gopal , Manchalwar V V 
Published: April 2017

Abstract
Mumbai Offshore fields are consisting of heterogeneous limestone reservoirs. Some of the reservoirs consist of tight carbonate with poor wellbore transmissibility. With the maturity of the fields, improving production from tight reservoirs has become the main focus for sustaining overall production. However, the responses of conventional stimulation techniques such as matrix acidization with self-diverting acid, deep penetrated acid, conventional acid fracturing etc. are not very encouraging in a tight reservoir, which calls for novel stimulation approach.
To address the issues, reservoir properties, well completion strategies and previous stimulation practices were analyzed in collaborative approach. Based on analysis, a different stimulation approach Closed Fracture Acidizing (CFA) was identified as the potential technique. Closed Fracture Acidizing reopens previously created fracture system with a pre pad fluid pumped at high rates. It involves creating fractures with a viscous fluid, letting it close followed by pumping a suitable acid system at matrix rate for etching the fractures. To improve treatment efficiency vis-à-vis better etched conductivity, different techniques such as leak-off control additives, effective diversion system, viscous acid systems etc. are applied.
For application of the technique, some low producing wells completed in Mukta pay of Heera field, A1 and L1 layers of Mumbai High field and Panvel pay of B-192 field were identified. The well specific treatments were designed by using Cross-linked Guar gel for creating fractures and a customized foamed acid system for etching of fracture faces. Foamed acid has been selected in these treatments for better exposure of acids in the entire fracture network and effective flow back of the treatment fluids. The foamed acid was customized by using a viscoelastic surfactant (VES) as foaming as well as viscosifying agent. Converting the acid system to stable foam greatly controlled fluid leak-off, increased the effective fluid volume and retarded the reaction rate, which is desirable in carbonate reservoirs. The various additives such as cross-linker, breaker etc. were optimized at onboard laboratory in the well stimulation vessel.
The jobs have been implemented in ten wells under constant monitoring of treatment parameters during fracturing, closure and acidization. Post CFA jobs indicate 670 bbl/day of oil production from a non-flowing well and significant improvement of productivity in other wells.
This paper describes the details of Closed Fracture Acidizing technique, treatment design, lessons learned during execution and results. The novelty of the approach over the conventional stimulation techniques in tight carbonate reservoirs are the treatment methodology and use of foamed acid system for better acid etched fracture conductivity.