bluuebunny/crossref_metadata_2025_split huggingface dataset:
First High-Rate Hybrid Fracture in Em-Yoga Field, West Siberia, Russia
Authors: Kaluder Zdenko , Nikolaev Maxim , Davidenko Igor , Leskin Fedor , Martynov Mikhail , Shishmanidi Irina , Platunov Andrey , Chong KK , Astafyev Vladimir , Shnitiko Andrey , Fedorenko Evgeny 
Published: February 2015

Application of horizontal multiple stage fracturing is becoming the standard completion technique for oil and gas developments both in Shale and Tight Sand. This technology has proven to be a game-changer for the United States oil and gas industry to the point of creating an oversupply of gas in United States. Predictions indicate that the supply of oil related to this technology could allow the United States to become self-sufficient within this decade. Globally, shale and tight sand exploration activities are also increasing. This concept was successfully suited to one of the Russian Tight Oil plays within the Em-Yoga license area in Western Siberia.
This paper provides the case history of how horizontal multiple fracturing completion methodology helped to unlock the potential Western Siberian Em-Yoga Tight Oilfield. This very heterogeneous and lenticular sand oil play was known for years for its complexity and arduous nature to extract oil from. The completion technique employed the proven North America multiple stage fracturing using a combination of swell-able packers and sliding sleeve frac ports. The fracturing design for the Em-Yoga field will be discussed in this paper. This design is an adaptation of an alternating hybrid fluid system composed of proppant slugs during the pad stage and a high concentration proppant ramp in the main frac stage.
The well is currently flowing at commercial rates synonymous with early production time in a typical North American oil shale well. In this paper, the authors describe the various monitoring techniques of how fracturing efficiency was measured. Earlier production allowed providing of fit curve production analysis to evaluate how the project is being commercially realized.
Analysis of Windows of Opportunity for Weather Sensitive Operations
Authors: Foo Yu Poh , Gan Kenneth , Giudice Dario , De Masi Giulia 
Published: February 2015

The paper presents an approach and real life results for the statistical analysis of operational windows for weather sensitive marine activities of limited durations (hours to days), based on the application of two statistical distributions: the four parameters Johnson distribution and the K distribution.
In the offshore industry, operations like heavy lift, pipeline tie-in, topside float-over can be carried out only when strict multi parameter limit conditions in term of wave height, wave period, wave direction - and, occasionally, wind and current speeds - are met over periods ranging from a few hours to a few days.
Reliable statistical analysis of occurrence and duration of such conditions - windows of opportunity - is an important planning tool to identify the most suitable season for operation, the vessel characteristics to minimize downtime and even the most appropriate operative approach - e.g. active vs. passive ballasting in float-over. This allows the minimization of overall cost and duration of the operation.
Present availability of long time series of metocean data, mostly from numerical models, allows the identification of windows of opportunity subject to complex sets of operative conditions, such as the concomitant occurrence wave, current and wind impacting on the vessel. However, the subsequent evaluation of the statistical properties (average duration, percentiles etc.) of operational windows from sample data is usually quite noisy, especially when the analysis is required on seasonal/monthly basis.
The robustness of the assessment can be improved with the use of suitable statistical distributions to fit sample data. In this context, the four parameters Johnson distributions and the K-distribution have the flexibility to fit windows of opportunity data and be used to evaluate their statistical properties.
The paper reviews the characteristics of both distributions, describes methods to fit them on sample data (estimators) and provides some examples of applications and preliminary comparison of performance with data and conditions derived from real life float-over operations.
TLP Motion Effect on Semisubmersible Motion
Authors: Abyn H. , Maimun A. , Jaswar Jaswar , Rafiqul Islam M. , Siow C.L. , Bodaghi Behnam 
Published: February 2015

The present paper studies numerically and experimentally hydrodynamic responses of a moored four columns semi-submersible with/without presence of another TLP shaped floating structure in regular waves. The six degree of freedom motions of the model moored on springs measured by the optical tracking system (Qualisys Camera) that captures the positions of the reflective optical tracking markers placed on the model. In numerical study, hydrodynamic problems are investigated by using HydroStar which is based on three-dimensional source distribution method, within the scope of linear wave theory and using frequency domain.
In recent years, the applications of floating platforms are going to be widespread with the exploration of oil and gas resources. They have moved to further than 2000m water depth and target the 3000m range. Unlike seagoing ships, moored floating offshore structures such as semisubmersibles and TLP are usually positioned at a given location at sea and their motion is externally constrained by the moorings. Motion response of a floating structure should be kept adequately low to guarantee the safety of risers and umbilical pipes as most important components in the equipment of oil production. The less amounts of motion the more safe operation is.
The experiment was conducted under condition as follows: time peak period (Tp) 1.85 – 2.15 second and significant (Hs) wave height 7.29 – 10 cm. Surge, heave and pitch response amplitude operation (RAO) of moored semisubmersible at different wave frequencies were plotted. Then the RAOs plotted for semisubmersible leeward of the other moored structure. The results of the floating structure interaction in surge, heave, and pitch motion were discussed and showed presence of TLP affect the motion responses of Semisubmersible in all directions.
This paper: Investigating the feasibility of installing two floating structures beside each other in deep water; evaluating the interaction effect on floating structure; evaluating amount of Response Amplitude of Operation.
A New Method for Wettability Alteration by Use of Cold Atmospheric Pressure Argon/Oxygen Plasma Torch
Authors: Heidari Mohammad A. , Habibi Ali , Ayatollahi Shahab , Sohbatzadeh Farshad 
Published: February 2015

Wettability is always an important issue for reservoir engineers. Wettability alteration is one of the significant indexes to show the capability of oil recovery of reservoir. In the recent years, various approaches to change wettability have been suggested by scientists and researchers such as chemical flooding and nanofluid injection. The purpose, in oil wet condition, is to change wettability to water wet condition to obtain more recovery. A lot of different methods for wettability measurement such as Contact Angle, Amott methods and USBM are proposed by Anderson and others. The most accurate method is contact angle for wettability measurement.
Plasma is one of the four fundamental states of matter. Heating a gas may ionize its molecules or atoms thus turning it into a plasma which contains charged particles: positive ions and negative electrons or ions. A nonthermal plasma is in general any plasma which is not in thermodynamic equilibrium, either because the ion temperature is different from the electron temperature or because the velocity distribution of one of the species does not follow a distribution. The effect of cold atmospheric argon/oxygen plasma torch based on dielectric barrier discharge was investigated on different surfaces. The experiments were conducted on the mica, glass slide and slice of dolomite core surface which is aged with oil and without oil and on a dolomite core with oil after waterflooding. The time interval of plasma torch treatment on these surfaces were 1, 3 and 5 minutes and contact angle measurements done 1, 14 and 28 minutes after plasma treatment. The range of contact angle decrease is between 5 to 41 degree and Fourier Transform Infrared Radiation (FTIR) spectroscopy was carried out for analysis of surface chemistry. It is worth mentioning, however, that it is a novel method and requires more investigation in order to be feasible in reservoir conditions.
Inflow Performance Relationship for Horizontal Wells Producing from Multi-Layered Heterogeneous Solution Gas-Drive Reservoirs
Authors: Khalid Muhammad Ali , Alnuaim Sami , Rammay Muzammil Hussain 
Published: February 2015

Oil well performance is measured by the assessment of its Inflow Performance & Outflow Performance Relationships (IPR & OPR).
Since 1968, Vogel equation has been used extensively for analyzing the IPR of flowing oil wells under solution gas drive. However, the Vogel curve was originally developed for vertical wells and may not be applicable to horizontal wells due to the fact that the flow into a horizontal well, with overlying gas cap, is different than flow into a vertical well. In addition, current used inflow performance relationship models for horizontal wells are impractical in nature, mainly developed for homogeneous reservoirs, and not suitable for multi-layered systems with different permeability. Thus, there is a need for new practical IPR model that considers the effects of reservoir heterogeneity on IPR curves for horizontal wells producing from two-phase reservoirs overlaid by gas cap.
This study investigates the effects of reservoir heterogeneity on IPR curves for horizontal wells drilled in heterogeneous reservoirs. To achieve the desired objective, commercial simulator Eclipse, is utilized to develop IPR's for horizontal wells producing from solution gas drive reservoirs. Firstly, a simulation model is developed where a base case is considered with typical rock, fluid and reservoir properties using black oil model. Dimensionless IPR curves are generated by obtaining a set of points relating flowing bottom-hole pressures to oil production rates. The effects of several reservoir and fluid properties such as bubblepoint pressure, oil gravity, residual oil saturation, critical gas saturation, initial water saturation, porosity and absolute permeabilities on the calculated curves are investigated. Reservoir heterogeneity is included in the simulation model by introducing the concept of semi-variogram function. Finally, an attempt is made to converge the results into one simple model in order to get a new empirical IPR correlation for horizontal wells producing from heterogeneous solution gas drive reservoirs suitable for systems with different reservoir permeability. The new empirical IPR model was then compared to the published correlations and found to have a small and acceptable average absolute error of less than 2%.
Application of Digital Core Analysis (DCA) and Pore Network Modeling (PNM) Based on 3D Micro-CT Images for an EOR Project in a Mature Oil Field in East Malaysia
Authors: Bt W Mohd Zainudin W. Nur Safawati , Md Zain Zahidah , Riepe Lutz 
Published: February 2015

For the optimization of an EOR project in a major mature oil field in East Malaysia, an extensive Routine and Special Core Analysis(RCA/SCAL) program has been performed on unconsolidated clastic reservoir rocks from a recently cored development well. Due to limited availability of suitable size of homogeneous core plugs for "conventional " flooding and lab experiments, a complementary analysis of petrophysical and mineralogical properties was performed based on the acquisition of high resolution 3D Micro-CT(MCT) images, SEM-EDX and application of Pore Network Modeling(PNM) techniques. Imaging enables to identify subregions of plugs damaged during coring and retrieval that remain in a good condition; from these region reliable static reservoir parameters are derived.
Generation of "static" parameters and a comparison with routine RCA/SCAL results, PNM simulations of primary drainage and imbibition, resulting pc, Kr curves and the residual oil saturations(ROS) were undertaken. Mapping of wettability highlights the impact of clay and its role in characterizing the multiphase flow properties. Investigations were performed to visualize effects of wettability changes due to cleaning, restoration and flushing of the cores by acquisition of MCTs at "native"and "restored" state conditions; variation of the ROS due to wettability changes were observed. The impact of wettability is directly quantified via PNM sensitivity studies. In view of the planned iWAG process to increase the recovery, water injectivity tests and formation damage studies in the lab were compared. Potential causes for formation damage were monitored and visualized by comparing registrations of 3D MCTs at different stages of the flooding and formation damage experiments.
The application of 3D MCTs and PNM proved to be a unique new option to visualize and understand the sensitivities during the handling of cores and to quantify potential effects of the experimental procedures on the multiphase flow in conventional flooding experiments. Thus, the Digital Core Analysis and PNM technology is a complementary alternative for the optimized investigation of EOR, especially in cases where the application of conventional laboratory investigations are limited due to the status of the core material and resulting potential experimental artefacts.
A Novel Model to Evaluate the Effectiveness of Polymer Flooding in Offshore Oilfield
Authors: Jiang Hanqiao , Chen Fuzhen , Li Yao , Zheng Wei , Sun Liang 
Published: February 2015

Polymer flooding has been widely used in the development of offshore oilfield as its significant EOR performance, which can achieve high oil recovery during the short service life of offshore platform. Effectiveness evaluation is an important aspect in polymer flooding application, and the results will affect the adjustment of polymer flooding. However, there is not too much study focusing on this field until now.
In this paper, an evaluation model was developed to estimate the effectiveness of polymer flooding. The response characteristics of polymer flooding were studied by the core flooding experiments. The comparison experiments of water flooding and polymer flooding were conducted to investigate the dynamic performance of production parameters during the flooding process. The results showed that the most significant performance is the "U" shape of water cut curve which indicate the effectiveness of polymer flooding. It also can be observed that the injection pressure and the oil recovery will increase when polymer flooding works, and their variation ranges have positive correlation with the effectiveness of polymer flooding. To get more details of geology and production parameters affect the polymer flooding effectiveness, numerical simulation model was built based on the data of Bohai oilfield. The influences of eight optimized parameters on polymer flooding effectiveness were studied by numerical simulation. Parameter sensitivity analysis was conducted by grey correlation method and the rank can be obtained according to the influence of each parameter on polymer flooding effectiveness. The results showed that mobility ratio, permeability variation coefficient and injection time are the top three parameters which indicate that they have more important influence to polymer flooding effectiveness. Then a multi-parameter response system was developed to describe the relationship between eight parameters and polymer flooding effectiveness. Consequently, a comprehensive effectiveness evaluation model was built which include the response characteristics summarization, parameter sensitivity analysis and multi-parameter response system evaluation. The effectiveness of polymer flooding can be evaluated and its key influence factors can be obtained by this model. It has been used in the evaluation of polymer flooding in Suizhong 36-1 well group in Bohai offshore oilfield in China, with inaccuracy of 7.83%.
Deepwater Subsea Waterjet Impact on HSE
Authors: Kivisto Bruce 
Published: February 2015

Deepwater subsea waterjet technology provides an opportunity to prepare for tier 2 and tier 3 oil spill emergencies and has been developed to enable safe, efficient and reliable means of addressing common subsea maintenance and repair operations.
Deepwater subsea waterjet technology extends well known surface-based waterjet techniques into the deepwater subsea space. It was developed in response to the Deepwater Horizon oil spill incident and is directly applicable to subsea emergency response situations. Several benefits resulting from the physical embodiment of deepwater subsea waterjet equipment make it desirable as a replacement to other traditional cutting equipment systems.
Inclusion of deepwater subsea waterjet cutting and blasting equipment in the group of normal maintenance and emergency response related assets proactively addresses several potential problems associated with other cutting methods. The equipment also opens several opportunities to enhance safety and efficiency of subsea maintenance and repair operations.
Problems:Limited ability to respond to tier 2 and tier 3 oil spills and/or oil and gas incidents resulting from exploration and production activities in deep and in ultra-deep water.Fire and explosion hazard when cutting into active flow lines.Risk of support asset entrapment when cutting loaded beams and support structures.Large mechanical stresses incurred when removing weight coating from flow line.
Opportunities:Increased diver and asset safety during routine and emergency response operations.Higher efficiency in decommissioning and maintenance activities.Acquire and prepare highly effective emergency response assets.
Diver and ROV safety is enhanced because the tool in a waterjet system cannot bind in the cut to cause entrapment of the asset thereby jeopardizing asset integrity. It also eliminates the gas pocket ignition hazard associated with some mechanical and thermal cutting methods. The equipment is operated via a single tether (umbilical) to reduce complexity and hazards aboard the deploying asset such as dive support vessel or production platform.
Floating Production Solutions for South East Asia
Authors: Spilker Maarten , Katarya Amit 
Published: February 2015

Historically, FPSO's have been the floating production solution of choice in Asia. Until 2012 only one Spar (Malaysia) and one TLP (Indonesia) has been installed. No Semisubmersible production units have been installed in South East Asia to date.
In the coming decade a large number of deepwater fields will be developed. We will see a large increase of TLPs, Spars & Semisubmersibles entering into operation. FPSO, TLP, Semisubmersible and Spar are proven solutions with mature technology and successful experience. They have been used for deepwater oil and gas production over many years worldwide. Different concepts bring with it advantages and limitations.
Before a field development concept is selected many design parameters need to be evaluated.
The primary drivers to be examined for concept selection are:Water Depth - Major impact on mooring designReservoir Shapes - Drilling requirementsMetocean ConditionsPayloadWell access requirements - Dry tree or wet tree.Availability of infrastructure and market locationPlatform DrillingImplication on Cap-Ex, Op-Ex for each concept
This paper discusses the selection criteria for application in Asia and also addresses design, fabrication and installation challenges. It will discuss the recent trend towards using Tender Assisted Drilling versus a permanently installed drilling facility and the associated challenges and solutions.
Vortex Induced Vibration and Thermal Cycle Analysis of a Complex Subsea Clad Jumper
Authors: Zhao D. , He N. , Feng X.H. , Yang H. , Sun G.M. 
Published: February 2015

PANYU 35-1/2 project loaded in South China Sea is designed to use rigid jumper to transport production fluid between two subsea components, for example, a well and a PLEM, or a PLEM and a PLET. The offset distance between the components (such as trees, flowlines, and manifolds) dictates the jumper length and characteristics. The petroleum resource in this field is high erosion (CO2 up to 17.2mol%), and usual under high pressure(up to 40MPa) and/or high temperature(up to 103°C), which turn out to be several technical difficulties for the jumper design. The assessment of the fatigue life of a subsea jumper subject to vortex induced vibration (VIV) and thermal cycle is a difficult and important engineering problem.
The paper focus on:State the key points of CRA clad pipe material used for the rigid jumper design, fabrication, and operation;When in areas of significant currents the jumper is subject to VIV. The complex shape of the jumper means that numerical methods are used to solve for the vibration modes of the jumper;Jumpers are expected to experience low-frequency/high-stress fatigue during successive heating and cooling cycles. Fatigue at the jumpers shall be evaluated based on expected number of cycles with FEA method;Coupling VIV and Thermal Cycle Analysis for the jumper, get the optimization method for the jumper design.
This paper examines each problem area, and sets out a optimization method, which is economical and practical for jumper design analyses.
Fit for Purpose Technology for Idle Well Reactivation - A Novel Application of Surface Jet Pump in Offshore Malaysia
Authors: Hassan Hani Sufia , Oktobaren Robby , Yahia Zaidil 
Published: February 2015

Brownfield is often associated with challenges to optimize production in cost effective manner due to declining well productivity and escalating cost. PCSB in its aspiration to reduce Idle Wells Inventory has extensively applied fit for purpose technologies to reactivate stranded oil and gas producers. This paper describes how such technology; Surface Jet Pump (SJP) provides solutions to reactivate oil producers in "J" field and gas producers in "A" field at two of PCSB's unmanned platforms, Offshore Malaysia.
"J" field is a marginal field development with minimal facility onboard. Full production stream is evacuated to the nearest facility via 53 km pipeline. Four years into production phase, some producers start to produce at high gas oil ratios (GOR) and high Flowing Tubing Head Pressures (FTHP) which created backpressure at the production header. Since the platform has no processing facility to manage the pressure variation, the high pressure (HP) wells had to be closed and allow the more productive low pressure (LP) wells to flow. Due to the space and power limitations on the platform, the feasibility of using SJP was assessed using network modeling. Following the assessment, SJP was installed in Sept 2012 and is deemed successful where it currently contributes between 11–15% of "J" field's total production and has reactivated 100% of the Idle Wells.
The "A" field, located offshore Peninsular Malaysia has 138 oil producers and 65 gas producers. Sixty of the gas producers located on one platform where there are two production systems; the HP for the non-associated gas and LP that is being utilized as three-phase production system. After seven years of production, the pressures in several gas wells have declined to the level that they are not able to flow to the HP system and became idle. SJP has been identified as an interim solution to produce the idle wells while waiting for booster compressor installation. The SJP was installed utilizing high pressure gas from HP compressor as the motive gas which has successfully reactivated 8 idle gas wells and boosted production on 4 other low rate gas wells with total production gain of 15 MMSCFD.