bluuebunny/crossref_metadata_2025_split huggingface dataset:
Successful Logging on Tractor in a High-Temperature Openhole Horizontal Well in a Tight Gas Field in the Sultanate of Oman
Authors: Briner Andreas , Nadezhdin Sergey , Tessari Sergio , Smit Jeroen , Busaidi Yazeed , Abri Mohammed , Mitri Joelle , Shalaby Ehab 
Published: January 2016

Abstract
This case study describes the deployment of logging tools on tractor in challenging wellbore conditions in a tight gas field in the Sultanate of Oman. Challenging conditions are defined by a high static temperature of 175°C; high static reservoir pressure of 72 MPa; a long, 5700-m wellbore; openhole configuration; and horizontal well profile. One of the conventional ways of deploying the caliper measurement in horizontal wells is through drillpipe conveyance. Deployment through coiled tubing conveyance is another option; however, this was not available owing to extensive logistical requirements and the operation's complexity. A newly developed openhole tractor designed for the well's extreme conditions was used to efficiently convey the logging tools. Features that enabled successful tool conveyance included the highest tractor force available in the industry, 6-drive tandem wheels, real-time adjustment of the radial force to the tractor arms, and active traction control for improved maneuverability. Calipers were successfully conveyed with the wireline tractor in the 800-m horizontal section of the 5000-m-deep well. The logging job took only 12 hours versus the traditional 60 hours required to convey the same tools on drillpipe. In addition, the tractor conveyance minimized the risks associated with operating at high temperature because it significantly reduced the time of exposure of tools to extreme high temperatures approaching their maximum temperature ratings, hence ensuring top performance and reliability. The fivefold time reduction also helped with the well economics and minimized the overall operational risks associated with the logging operation. The recorded caliper data enabled proper evaluation of the hole conditions for selecting the best location for setting the swellable packers.
Strategically Increasing Completion Efficiency by Applying a Customized Filtercake Breaker Solution
Authors: Alimuddin Sultan , Yewlekar Satish , Raman C. V. , Bais Shashi Kant , Anez Marcos , Ezeigbo Eze , Kishore Kunal , Patil Bhushan 
Published: January 2016

Abstract
This paper presents a comprehensive field study of an openhole completion with standalone screens using a unique filtercake breaker treatment, compatibility with reservoir fluids, cost effectiveness, and overall performance-based comparative results to meet the challenges of drilling and completing offshore wells.
In the offshore field of Krishna-Godavari Basin, Bay of Bengal, one of the most prolific hydrocarbon basins of India, synthetic-based reservoir drill-in fluids (SB-RDFs) were used to drill the reservoir section, which was then completed openhole using standalone sand-control screens. In order to control fluid invasion to the formation, a major cause of formation damage, the designed RDF created a filtercake at the sandface. However, high flow initiation pressure caused high skin effect and compromised completion efficiency. The primary challenge during completion was to clean up the SB- RDF filtercake from the reservoir section to remove near-wellbore damage and maximize productivity. Another challenge was to avoid the high potential of filtercake plugging of the screens, which could lead to higher drawdown pressures and possible early screen failure. To address these challenges, a filtercake breaker for the SB-RDF was developed to lower the skin factor thus maximizing production and mitigating the risks of plugging the sand-control screens. After implementing this customized breaker solution, combined with a precise placement program, the wells showed a tremendous reduction in the skin factor and a significant increase in completion efficiency, compared to wells with the same reservoir properties completed in earlier campaigns.
An organic acid pre-cursor enabled filtercake breaker placement and soaking without being chemically spent during circulation. Additional breaker design criteria included the ability to break the RDF emulsion, water-wet the solids in the filtercake, dissolve the calcium carbonate used as bridging material in the SB-RDF, and disperse the non-acid soluble material without plugging the screens.
The paper presents a detailed study of the main challenges while formulating and evaluating the filtercake breaker solution. Additionally, a production results comparison is made between the well using the customized filtercake breaker treatment and previous well completion and breaker treatments. The paper also discusses the comprehensive displacement program and required spacers for precise placement of the breaker in the openhole and offshore pit management.
Buoyancy Technology Used Effectively in Casing Running Operations: Case History of Record Length Two-Stage Production Casing String
Authors: Rogers Hank , Shaikh Alaa , Faraj Omar A. , Hasan Abdulaziz 
Published: January 2016

Abstract
Operators today face an ever increasing demand for locating commercial reserves and producing those reserves with attention to exploration and development costs. In addition to basic financial pressures, operators also strive to reduce the environmental impact of well construction and production operations. Extended-reach drilling technology allows operators to reach recoverable reserves that, in the past, were unreachable. Specifically, extended-reach drilling from a multi-pad wellsite allows significant portions of the well construction costs to be spread over multiple wells, rather than being carried by an individual wellbore. Also, the ability to drill multiple wells from a single pad helps reduce the environmental impact from the drilling operation.
Extending the wellbore reach from a given pad depends on the location of the target formation. Depth, horizontal distance, and production type significantly affect the type of drilling program as well as the casing running operation. In many wells, drag between the casing and wellbore prevents casing running operations from being performed. Casing flotation is a proven technology that has been deployed in multiple fields globally to extend the attainable lateral reach of the casing running operation.
This paper documents using flotation technology in combination with two-stage cementing tools in production wells where drag limits and subsequent casing lock up were averted to allow successful casing running operations to be performed. Detailed pre-job planning and computer simulations are provided to demonstrate the technical limits and step-out achieved with casing flotation.
Successful Use of Abrasive Tubing Punch Technology for Highly Deviated Wells in Saudi Arabia
Authors: Danish Syed Muhammad , Khan Faisal Zubair 
Published: January 2016

Abstract
The scope of this paper is to highlight the difficulties faced together with the respective solutions proposed and executed during the de-completion of a deviated well having complex horizontal internally plastic coated (IPC) completion during its work over phase, for a sour gas field. This was the first instance an abrasive jetting technology was used to punch a completion during a workover operation in Saudi Arabia.
In an unrelenting pursuit to reduce rig time per well, operators have to explore new innovative technologies that can reduce their reliance on multiple intervention techniques, subsequently saving rig stand by and operating hours by cutting unnecessary trips in and out of the wellbore.
In this candidate onshore well, the operator wanted to identify, isolate, and eliminate downhole tubing casing annulus (TCA) communication by changing the existing IPC completion. The production region was a deep horizontal openhole section with the reservoir having high gas oil ratio (GOR), based on previous experience the well was expected to produce sour gas any time even when it is killed. Initial operation on the rig was to nipple down (N/D) the wellhead (WH) and nipple up (N/U) the rig's blow out preventer (BOP) by loading up the well with kill fluid and setting secondary mechanical isolation barriers for well control. It was unfeasible to cure kill fluid losses using loss circulation material (LCM) because of the large openhole section, the highly deviated completion further limited slickline or wireline reach for barrier placement.
This paper explains the innovative solution devised and executed on this well, further covering the execution part of the operation, elaborating the combination of coiled tubing (CT) with slickline tools for intervention, tubing punch by abrasive sand blend jetted by means of specifically designed carbide nozzles, and the implementation of best practices to deliver a successful TCA isolation and well de-completion in record time.
The operation consisted of multiple CT runs, from cleaning out the completion of any residue plastic junk to lock mandrel enabled leak isolation, and mechanical plug barrier placement before abrasive jetting for tubing punch just above the packer with depth correlation by memory casing collar locator (CCL). Based on similar work performed on a nearby well, this innovative abrasive punch technology enabled the rig to save more than 40 hours of operating time on Well X.
Achieve Demanding Targets: Successful Well Placement With No Harm to the Environment. Case Study from Offshore Abu Dhabi
Authors: Al-Jaberi S. M. , Amer M. M. , Marrauld J. , Yuliandri Y. , Al-Braik S. , Baca Espinoza I. , Shoukry M. , Hammad T. K. , Jaorawala A. , Herz U. , El Masry H. , Saravanakumar K. , Potshangbam S. 
Published: January 2016

Abstract
Drilling and producing oil wells safely and with minimum risk of environmental hazards is crucial in Abu Dhabi offshore fields. A significant challenge to achieve this goal is steering in very selective sub-layers without conventional radioactive source porosity tools. Acquiring real-time data is critical, especially when drilling slim holes with long horizontal drains, and a well profile that targets several thin reservoir beds.
To meet this challenge, a nuclear magnetic resonance (NMR) sourceless porosity tool was introduced for the first time in this reservoir in a six-inch hole. Two lateral drains, each more than 3,000 ft., were drilled, targeting different reservoirs. As a part of the geosteering methodology, nearby offset well properties were incorporated to generate a forward model along the planned well trajectory. The forward integrated geosteering model was updated in real time with porosity and gamma ray data, resistivity images and, structure views, etc. Decisions were made from this input to place the trajectory in the optimum target zones, achieving the reservoir objectives.
This paper demonstrates the successful use of an NMR sourceless tool's real-time data acquisition that played a significant part in facilitating effective geosteering and well placement. Real-time NMR total porosity was critical to confirm optimum well placement, especially where lateral facies variations were expected and due to the limited availability data for such a green field. In addition, the available porosity distribution was used to estimate a permeability index. This index, after normalization to offset the well data, was used for selecting formation pressure while drilling and reservoir zonation.
The case study in this paper shows that with current advance technologies, incorporated data for available wells, and real-time technical support, the demands of sourceless drilling can be achieved to place the well in a precise target during slim borehole drilling.
Step Change in Drilling Efficiency
Authors: Salem Gamal 
Published: January 2016

Abstract
Step change in drilling effiency to enhance drilling performance in our field.
Our casing design in our field heavy casing design as drill 22″ hole and set 18.5/8″ casing at +/- 2000 ft and drill this phase with RSS to control the verticalitly in the hole as our wells drilled in cluster location the separation between each wells is 10 M only so the verticalitly is very important to avoid anti collsions between the wellsso 1st phase the quality to drill the hole and run casing is very important than make perfroamnce.
Second phace in our casing design is 16″ phase which will drill it deviated section up to +/- 9000 ftand will discuss it in detail after complete discsions the remain phases in our casing design.
Subsurface Wireless Intervention Technology Development for the Acquisition of Subsurface Static and Dynamic Fluid Level in Oil and Gas Wells
Authors: Littleford S. J. , Holyoak S. , Birch W. , Shepherd D. 
Published: January 2016

Abstract
This paper summarizes the results of an eight well field trial that utilized a wireless surveillance technique to measure real-time wellbore fluid interface depths. The measurement of fluid depth in oil and gas wells is widely used for calculating reservoir pressure in the absence of downhole gauges and for other well information requirements. As this innovative technology does not require well entry it reduces operational costs and exposure to HSE risks. Furthermore, this technique overcomes issues inherent in acoustic measurement, related to low-pressure environments and short distance measurement.
The novel Frequency and Time Domain Reflectometry (FDR/TDR) technique described in this paper utilizes Microwave (MW) and Radio Frequency (RF) to scan the inside of the tubing string from the wellhead to a subsurface feature. The scanning operation consists of injecting pulses of MW/RF frequencies through the wellhead via an antenna installed in a Tree Cap or the annulus. The core advantages of the technique are: Low energy MW/RF pulsesWell pressure control and well entry tooling requirements are minimizedPre-determined MW/RF frequencies for tubing scans are harmonized with completion geometry to optimize measurement efficiencyThe scanning process takes approximately one minuteData processing of the scan information identifies single and multiple fluid level interfaces in addition to other well features.The data is available immediately and displayed on a surface readout unit (SRU).
The average rig up to rig down time taken for each well was approximately forty minutes. The position and movement of the well bore fluid levels and other well features such as tubing joint identification were successfully measured providing data for the analysis of the well fluid inventory. The identification of individual casing and tubing joints allowed depth correlation to be verified to previously measured depths and provided a simple method of calibration. The technique provided accurate measurements over short and long distances.
The trial provides evidence of the successful development and implementation of a wireless field deployable subsurface well surveillance sensor. The sensor technology is designed for deployment in single and multiple well applications used for continuous monitoring of well integrity and for production optimization purposes.
Further development of the sensor has advanced by focusing on the introduction of the technology to multiple wells and remote surveillance real-time monitoring operations for both tubing and annulus fluid level measurements.
Combination of Foam Assisted Lift & Gas Lift (FAGL) to De-liquefy Gas Wells
Authors: Tayyab Imran , Uddin M. Farooq , Ahmed Qazi I. , Ibad-ur-Rehman M. , Azam Qazi Syed 
Published: January 2016

Abstract
Liquid loading is an ineluctable problem encountered by gas wells as their reservoir pressure declines and Gas-Liquid Ratio (GLR) increases. Foam Assisted Lift (FAL) is one of the modern methods for dewatering gas wells by reducing effective density and surface tension of produced fluid. Gas lift is also a widely used method that reduces flowing bottom-hole pressure by injecting gas in the well to lower hydrostatic head.
This paper proposes a combination of above mentioned technologies called Foam Assisted Gas Lift (FAGL) and recommends its' efficiency over two specific scenarios; a) when reservoir pressure is low and static liquid level remains below bottommost SPM, b) when there is a considerable liquid column in wellbore and gas injection pressures are limited due to surface constraints, injecting foam decreases the hydrostatic head and requires less gas injection pressure to offload the well. In either case, FAL can offload the well but the stabilized rates achieved are uneconomical compared to the soap requirement per day. FAGL is applied on mature wells having low reservoir pressures and completed with single SPM. These wells had frequent load-up issues and FAL/gas-lift failed due to low reservoir inflow. After FAGL is implemented, frequent load-up issues have been resolved and wells began to produce at increased stabilized rates. FAGL also emerged as an economical option because it reduced the soap /injected gas requirement per day and increased gas rates and overall recovery.
For wells with deep SPMs, depleted reservoir pressure and liquid loading problems, FAGL could be an economical de-liquefaction method when compared to standalone gas-lift or FAL due to its lower OPEX.
Reducing Depression Through an Online Intervention: Benefits From a User Perspective
Authors: Crisp Dimity A , Griffiths Kathleen M 
Published: January 2016

Background
Internet interventions are increasingly being recognized as effective in the treatment and prevention of mental health conditions; however, the usefulness of such programs from the perspective of the participants is often not reported.

Objective
This study explores the experiences of participants of a 12-week randomized controlled trial of an automated self-help training program (e-couch), with and without an Internet support group, targeting depression.

Methods
The study comprised a community sample of 298 participants who completed an online survey both prior to and on completion of an intervention for preventing or reducing depressive symptoms.

Results
Overall, participants reported a high level of confidence in the ability of an online intervention to improve a person’s understanding of depression. However, confidence that a website could help people learn skills for preventing depression was lower. Benefits reported by participants engaged in the intervention included increased knowledge regarding depression and its treatment, reduced depressive symptoms, increased work productivity, and improved ability to cope with everyday stress. A minority of participants reported concerns or problems resulting from participation in the interventions.

Conclusions
The findings provide consumer support for the effectiveness of this online intervention.

Trial Registration
International Standard Randomized Controlled Trial Number (ISRCTN): 65657330;http://www.isrctn.com/ISRCTN65657330 (Archived by WebCite at http://www.webcitation.org/6cwH8xwF0)
Microsurgical resectability, outcomes, and tumor control in meningiomas occupying the cavernous sinus
Authors: Nanda Anil , Thakur Jai Deep , Sonig Ashish , Missios Symeon 
Published: January 2016

OBJECTIVE
Cavernous sinus meningiomas (CSMs) represent a cohort of challenging skull base tumors. Proper management requires achieving a balance between optimal resection, restoration of cranial nerve (CN) function, and maintaining or improving quality of life. The objective of this study was to assess the pre-, intra-, and postoperative factors related to clinical and neurological outcomes, morbidity, mortality, and tumor control in patients with CSM.

METHODS
A retrospective review of a single surgeon's experience with microsurgical removal of CSM in 65 patients between January 1996 and August 2013 was done. Sekhar's classification, modified Kobayashi grading, and the Karnofsky Performance Scale were used to define tumor extension, tumor removal, and clinical outcomes, respectively.

RESULTS
Preoperative CN dysfunction was evident in 64.6% of patients. CN II deficits were most common. The greatest improvement was seen for CN V deficits, whereas CN II and CN IV deficits showed the smallest degree of recovery. Complete resection was achieved in 41.5% of cases and was not significantly associated with functional CN recovery. Internal carotid artery encasement significantly limited the complete microscopic resection of CSM (p < 0.0001). Overall, 18.5% of patients showed symptomatic recurrence after their initial surgery (mean follow-up 60.8 months [range 3–199 months]). The use of adjuvant stereotactic radiosurgery (SRS) after microsurgery independently decreased the recurrence rate (p = 0.009; OR 0.036; 95% CI 0.003–0.430).

CONCLUSIONS
Modified Kobayashi tumor resection (Grades I–IIIB) was possible in 41.5% of patients. CN recovery and tumor control were independent of extent of tumor removal. The combination of resection and adjuvant SRS can achieve excellent tumor control. Furthermore, the use of adjuvant SRS independently decreases the recurrence rates of CSM.
Skull base chordomas: clinical outcome in a consecutive series of 45 patients with long-term follow-up and evaluation of clinical and biological prognostic factors
Authors: Boari Nicola , Gagliardi Filippo , Cavalli Andrea , Gemma Marco , Ferrari Luca , Riva Paola , Mortini Pietro 
Published: January 2016

OBJECTIVE
Skull base chordomas (SBCs) are rare dysembryogenetic invasive tumors with a variable tendency for recurrence. According to previous studies, the recurrence rate seems to be affected by both clinical variables and tumor biological features. The authors present the results of treatment of SBCs in a large series of patients and investigate the role of 1p36 chromosomal region loss of heterozygosity (LOH) as a prognostic factor.

METHODS
Between 1990 and 2011, 45 patients were treated for SBCs. The mean follow-up was 76 months (range 1–240 months). An LOH analysis was performed in 27 cases. Survival analysis was performed to determine clinical and biological parameters correlating with clinical outcome.

RESULTS
The 5- and 10-year overall survival rates were 67% and 57%, respectively. Five- and 10-year progression-free survival rates were 58% and 44%, respectively. Multivariate analysis showed that extent of resection, adjuvant radiation therapy, and absence of rhinopharynx invasion were positive independent predictors of overall survival. The latter 2 variables and a younger patient age were positive independent predictors of progression-free survival. Twenty-one patients showed 1p36 LOH. All events of recurrence and death clustered in the group of patients with 1p36 LOH; however, this biological marker was not statistically significant on multivariate analysis.

CONCLUSIONS
Resection is the treatment of choice in primary and recurrent SBC. Patient age, rhinopharynx invasion at diagnosis, extent of tumor removal, and postoperative radiation therapy influence SBC prognosis. Genetic analysis, even while showing interesting results, did not reveal 1p36 LOH as an independent predictor of clinical outcome.