bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Novel High Temperature Insulating Packer Fluid
Authors: Eriksen Kjetil , Panamarathupalayam Balakrishnan , Foxenberg William E. , Chumakov Eugene 
Published: September 2014

Abstract
Drilling and completing wells in arctic areas pose many challenges, one of which is the tendency of permafrost to slowly thaw with production and cause wellbore integrity issues in later well life. With arctic exploration moving offshore, ensuring the integrity of the well for the productive life of the field is becoming even more crucial, as a well failure can potentially threaten to close down an entire production facility. Arctic permafrost is an example of an environment that can be disturbed during normal production operations due to heat transfer. Insulating the wellbores is a desirable practice; however, in many cases a suitable technology is either not readily available or not economically viable. Placing an insulating fluid in an annulus can be a practical and sustainable solution. Insulating fluids have been deployed in some cases but for various reasons, results have been less than satisfactory. This paper presents results of laboratory studies of a novel, 100% base oil system that provides sufficient viscoelastic yield stress to prevent convective heat loss though an annulus. The rheological properties necessary to reduce heat loss is achieved with this fluid at temperatures up to 150 &deg;C. This viscoelastic property is obtained without the need for cross-linking agents that require complex mixing procedures and are sensitive to contamination. This paper also compares heat transfer properties of various packer fluids such as base oil, brine, viscosified brine and this novel gelled system. The ability to eliminate convective heat loss in combination with its intrinsic low thermal conductivity means that this fluid is an excellent candidate as an insulating packer fluid.
Provision of Shale Sediment Stability in Deviated (Horizontal) Wells
Authors: Rastegaev B. A. , Gnibidin V. N. , Nozhkina O. V. , Dorovskikh I. V. 
Published: September 2014

Abstract
The problem of stability wellbore appears especially true when buroenii horizontal wells. This paper presents the results of stability analysis of rock Mukhanovskoye field. Also offers advice on selecting inhibited drilling fluid systems.
The relevance in consideration and in the forecast of massif rock tension that contain oil and gas-saturated reservoirs is characteristic for the majority of the fields complicated by the abnormally high formation pressures (AHFP) [1]. Besides now they start the development of the fields with hard-to-recover reserves characterized by complex rock-and-geological conditions, low permeability and poor development of infrastructure. One of problems related to these fields consists in poor knowledge on regional stresses in the fields and sharp variability of magnitudes and orientation of horizontal stresses by depth. The stress condition of the rock produces significant impact upon the wall stability in the well especially in its horizontal sections. Need to consider the stress direction and its magnitude while selecting the well construction and completion procedure is related to their influence upon the direction of natural fracture system development and the dependence of fracture direction created by hydro-fracturing operations upon the natural stress status that subsequently has significant impact on the production volume [2]. For fields in development this need is connected with their impact upon the oil and gas production, as well as with the application of some production stimulation procedures and their effect upon the stress local fields. Change in formation pressure, arrangement of formation pressure maintenance system, extensive application of reservoir hydro-fracturing jobs conducts the redistribution of stresses and tensions in the rock near some wells, and sometimes for the whole field [3]. Indirectly this is confirmed by expansion of areas connected with the technogenic seismicity caused by field development process. Thus, it’s required to have continuous monitoring over the rock stresses in the area of hydrocarbon fields and the consideration of the information received by these measurements while constructing the wells and developing the fields using the oil production stimulation procedures [1].
The monitor of excessive or abnormally high formation pressure (AHFP) should be considered as the versatile aspect that combines the elements of geology, rock mechanics, chemistry and engineering. For this it's required to have the information on regional geological history as well as the results on detailed studies for the wells drilled closely or directly across the territory under study.
An Integrated Experimental Approach to Determining How Invaded Mud Components Modify Near-Wellbore Properties
Authors: Mikhailov D. , Ryzhikov N. , Shako V. , Theuveny B. 
Published: September 2014

Abstract
At different penetration depths, mud-component invasion creates multizone structures in the vicinity of the wellbore. These structures include external mudcake (mud particles and mud clay deposited at the sandface), internal mudcake (which is formed by mud particles invaded into the reservoir formation), and mud-filtrate invaded zone.
We present a new technique for estimating empirical parameters of both external and internal mudcake by combining laboratory data on mud flooding experiments and measurements of the profile of the invaded mud components by X-ray microcomputed tomography (XmCT), image processing of core cross-section photography, and ultrasonic wave scanning.
The technique is validated on flooding experiments with simple ("model") muds: slurry of bentonite clay, suspended solid particles and polymer Xanthan.
Examples of reconstructed profiles of invaded mud components (solid particles and bentonite clay) as well as the procedure of determining internal mudcake parameters are provided.
Improving of Cleaning Efficiency of Oil Pipeline from Paraffin
Authors: Turbakov Mikhail S. , Riabokon Evgenii P. 
Published: September 2014

Abstract
The purpose of this paper is to present and analyze wax deposition mechanism on the inner oil pipe wall. It is shown that the factors such as pressure, temperature, wettability nature of washed surfaces, velocity of the oil during oil pipeline transportation, as well as resin asphaltene and hard paraffin concentration in the reservoir oil play key role in the wax matter deposition. The pigging tool which removes wax deposits is proposed. The advantages of this tool are compared with analogues. It is shown that tool increases operation reliability, oil pipeline life, high grade cleaning of oil pipeline in the curved areas and has low-cost production.
A New Engineering Approach to Hole-Making Position Control on the Arctic Shelf
Authors: Binder Ya. I. , Gutnikov A. L. , Paderina T. V. , Polienko V. N. , Rozentsvein V. G. , Klyushkin P. A. , Sokolov D. A. 
Published: September 2014

Abstract
The efficiency of developing new oil and gas resources on the Arctic shelf is substantially dependent on how perfect the drilling techniques and technologies are. The paper presents the results of the research and development carried out over the last few years by a consortium of marine and geophysical instrument engineering companies led by Concern CSRI Elektropribor (St. Petersburg, Russia). The discussion is focused on the original engineering approaches to designs, algorithms, and methods applied to solve the main problems encountered in offshore drilling of oil and gas wells and, in particular, at high latitudes.
Oil and gas deposits in the Arctic shelf are one of the major world energy resources, the exploration of which is among the main strategic objectives of Russia. One of the most critical problems to be solved within the Arctic project is creation of equipment for hole-making position control and monitoring of earlier drilled oil and gas wellbores. This is a challenge, as the designers should keep in mind such different kinds of problems as the unique natural conditions of the Arctic and a specific character of navigation at high latitudes, which makes control and monitoring intricate problems;shelf-typical problems of hole-making position control associated with specific configurations of the holes as well as hydrology and geology of the stratum separating the hole bottom and the day surface;world trends in hole-making position control technologies.
The engineering approach presented in the paper is concerned with most of the urgent problems encountered in drilling wellbores on the Arctic shelf. The research combines and develops alternative and traditional approaches but in both cases, the problems are resolved in a novel original way.
Horizontal Drilling with Multi-Stage Fracturing - Access to Challenged Reserves of Tyumen Formation, Krasnoleninskoye Field
Authors: Nemirovich Gennadiy , Islamgaliev Rustam 
Published: September 2014

Summary
This paper describes the main issues and challenges complicated the full-field development of the Jurassic deposits of the Tyumen Formation (JK2-9), Krasnoleninskoye Field. The paper summarizes the conclusions of actual wells operation, as well as substantiates the development strategy for heterogeneous low-permeable reservoirs. The results obtained were used as a base for HW+MSF technology piloting on Em-Egovskaya area, the most promising area in terms of reserves of the Tyumen Formation, Krasnoleninskoye field. At the time of paper generation, the pilot project moved to the next stage – rolling-out of engineering solutions on contingent areas (drilling of additional well clusters). However, the main focus of this paper is placed on the first stage of the pilot project including development strategy definition.
Complex Waterflood Management in Mature Oil Fields
Authors: Ilyasov Ilnur 
Published: September 2014

Abstract
Pressure maintenance system in mature oil fields plays very important role and increase in field development efficiency is impossible without increase in waterflooding efficiency. Complex waterflood management consists of both organization and technological methods.
Suggested to use waterflooding analysis based on fileld development patterns, taking into account geological structure, instead of development blocks, that will help to make more detailed and reliable analysis of voidagecompensation. Second suggested method is to use streamlines. As technological metod it is suggested to use technology of discrete injection, main idea of which in changing working regime of injection wells from continious to discrete and in organization of the whole waterflood system in cyclic regime. Pilot sector was chosen, assessment of suggested methods and calculation of possible effect was made, which gave positive economic effect.
The Deployment of Managed Pressure Drilling Technology, to Assist in the Development of Offshore HPHT Gas Condensate Fields in Vietnam - Planning, Engineering, and Implementation
Authors: Gedge Ben , Yong Tan Chai , Rao Jordan , Singh Harpreet Kaur , Oracion Joseph , Quoc Bao Ta , Bot Nguyen Viet , Tran Nam Hong , Minh Tri Le , Buitenhuis Richard , Dai Lich Tran , Wittry Alan E. , Malpas Peter , Beaugeois Aldric , Huu Nhieu Nguyen , Que Nguyen Van 
Published: September 2014

Abstract
The paper discusses two gas condensate development projects in Vietnam, which have and are deploying Managed Pressure Drilling (MPD) Technology.
Bien Dong POC in 2010 commenced planning for the Bien Dong 1 High Pressure High Temperature (HPHT) gas condensate development project offshore Vietnam, with bottom hole pressures of 15.2lb/gal - 17.2lb/gal, and with bottom hole temperatures in the range of 155 deg C - 180 deg C. With very narrow kick loss margins inside 0.5 lbs/gal, the probability of serious kick loss issues during the drilling of the reservoir sections looked to be very high. The Bien Dong 1 development is a complex HPHT project ranking one of the most difficult and challenging HPHT projects in Asia Pacific currently.
As a remedy for such potential drilling hazards, Managed Pressure Drilling techniques and technology were selected, and implemented. This technology gives the option for accurate early kick detection and if required Constant Bottom Hole Pressure (CBHP) drilling coupled with ECD management.
The second project which deployed MPD Technology is the gas condensate development for Cuulong JOC, with lower pore pressures than Bien Dong 1 the range of 12.5lb/gal - 14.0lb/gal but with bottom hole temperatures up to 190 deg C static.
The paper will examine the following Reasons and conceptions to use managed pressure drilling technologyPreplanning and engineering of the projectManaged pressure drilling equipment adaption into a new build semi-submersible tender assist, quad mast rig, including modifications to the hook up of the 15K BOP stack and expanded mud gas separator systemImplementation of the project once the rig was on location in readiness to commence drilling the first wellRig crew familiarization and training in MPD techniquesAnalysis of the early results in the project
Application of an Innovative Cement Spacer to Improve Zonal Isolation - Indonesia Case Histories
Authors: Farahani Hamidreza S. , Budiawan Aditya , Brandl Andreas , Mohamed Mickael , Sasmita Minda , Ardian Iwan 
Published: September 2014

Abstract
This paper reviews the challenges faced during well cementing in the fields of Indonesia and describes the use of an innovative cement spacer to successfully solve these issues. Unconsolidated formations, natural fractures, and depleted reservoirs are the main causes for lost circulation during drilling and cementing operations, often resulting in poor zonal isolation and failed Top of Cement (TOC) requirements. The common practice to address these well integrity problems is to apply lost-circulation materials and low-density cementing systems which did not always yield the desired results. As a result, remedial cement squeeze jobs were needed in many primary cement jobs.
To overcome these challenges, an innovative cement spacer system was engineered and applied. The environmentally preferred spacer system contains a biopolymer to mitigate lost circulation issues during cementing. It strengthens the wellbore wall by forming an effective seal along the formation, minimizing losses and preventing cement fallback after placement. In cases of severe or total loss of returns, a special Lost Circulation Material (LCM) can be added to the spacer system which enhances the performance of the spacer by allowing it to adhere to the lost circulation zone(s). The special LCM technology is a blend of 100% organic biodegradable, lost circulation materials.
The initial field application was immediately successful in obtaining full circulation returns during cementing, a constant challenge on many jobs in the fields of Indonesia. An additional advantage in some areas was that the cement slurry density could be increased from lightweight (10.5 ppg) to conventional (15.8 ppg) without encountering losses, despite exceeding the maximum theoretically allowable equivalent circulating density (ECD). The increased slurry density improved early cement strength development, which reduced wait-on-cement times and eliminated the requirement for expensive lightweight cement materials. This, in turn, simplified operations and logistics, and reduced costs.
Multiple case histories are presented covering more than 70 successful cement jobs using the innovative sealing spacer system. Specific cases are discussed where successful results were achieved despite partial to total losses during the drilling phase; where cement bond logs have improved; where severe to total losses have been cured by the addition of special LCM and where remedial jobs have been eliminated. Conservative cost savings with the new spacer design were conservatively estimated to be more than 4 million USD.
Near Wellbore Asphaltene and Wax Remediation Using In-Situ Heat Generation in Both PCP and Non-PCP Wells: Concept, Operational Challenges & Remedial Solutions
Authors: Goenka S. K. , Singhal J. , Kothiyal M. D. , Parasher A. , Tiwari S. 
Published: September 2014

Abstract
Deposition of paraffins and asphaltenes in the near well bore region has always been one of the most studied cause of production decline especially in brown fields. Pumping heated fluids, inhibitor pumping, or mechanical methods of clean out using coiled tubing jetting or jointed pipes are some of the industry prevalent methods of countering this issue. But these methods are both cost and time consuming with short lasting results. With industry constantly marching towards the production of more and more ‘difficult oil’ it has become the need of hour to devise and deploy more cost and time efficient methods to mitigate the problem.
The paper highlights the application of In-Situ Heat generation methodology and details the execution process used to mitigate the near wellbore wax deposition in field X in western part of India. Field X in India has been developed as an onshore field wherein wells are drilled in shallow reservoir. To support the oil production, some wells are produced using Artificial Lift techniques like PCP. Crude of the reservoir is high in wax content with pour point at 60 °C which is very close to reservoir temperature (~65 °C) resulting in high wax deposition against screens & near wellbore. The wax dissolution temperature is well above the reservoir temperature, due to which any effective remedial treatment necessitates higher temperature generation for dissolution/inhibition of wax problems.
In-Situ Heat generation methodology is based on the concept of down-hole heat generation by exothermic chemical reactions. The paper details the operational challenges observed while conducting the operation in both PCP and non-PCP wells and various measures taken to mitigate the same. Steps in developing this system and using it in the field are documented, and the challenges encountered, lessons learnt and recommendations for future application of the system are described.
Edge-Water Drive Recovery Enhancement by Induced Fines Migration
Authors: Zeinijahromi Abbas , Al-Jassasi Hammam , Zhang Yizhong , Begg Steve , Bedrikovetsky Pavel 
Published: September 2014

Abstract
Oil bypassing is a significant problem in edge-water drive reservoirs. The encroaching water from an active aquifer overruns oil and leaves a significant volume of trapped residual oil behind. This causes pre-mature water production and early well abandonment. The technique to inject small volume of low salinity water into abandoned wells in order to create a low permeable barrier against the water fingers is presented. In addition a method of applying commercial reservoir simulators to model the process is introduced. The modeling results shows that injection of small volume of low salinity water results in increasing reservoir production life and consequently 4.5% incremental recovery if compared to normal depletion. The economic evaluation of the technique resulted in NPV value of +7.84 MM US$ meaning that the technique is viable from economic stand point.
Cluster LNG – New Paradigm for Small and Medium LNG Business
Authors: Lee JungHan 
Published: September 2014

Abstract
Small and medium scale LNG is different from conventional LNG in trading distances, target markets, and application areas. Small and medium scale LNG may liaise needs between regional gas producers and consumers. Restrictions and differences of the regional energy tasks may call for different approaches in technology and business model. Cluster LNG is new concept LNG technology suitable for the emerging market environments. High performance of Cluster LNG is originated from higher liquefaction temperature and the adoption of efficient refrigerants for the temperature ranges. The inherent high performance of Cluster LNG enables low CAPEX and low OPEX. Despite of increased containment system cost over Conventional one, cost reduction in the Cluster LNG liquefaction system prevails overall economics within 3,000 ~ 5,000 Km distance from production to consumer sites. The high performance of the Cluster LNG brings competitiveness in small and medium scale LNG business requiring 75 ~ 85% of CAPEX and 65 ~ 75% OPEX compared with Conventional one. In addition, the CO2 emission per unit LNG production for Cluster LNG is 60 ~ 70% of the Conventional LNG. The Cluster LNG technology and business is well matched for small and medium LNG business with cost-effectiveness and flexibility. After extensive engineering verifications and test plant operations, several commercial Cluster LNG projects are under negotiation stages. The Cluster LNG technology also increases local contents with wider choices of equipment vendors and system providers together with less project budgets. Flexibility and cost competitiveness of the Cluster LNG would bring paradigm change in small and medium LNG business.
Generation of Representative PVT Properties through an EOS Model by Integrating Multiple Partial Datasets
Authors: Das Gunajit , Khan Hasnain , Singh Chander Shekhar , Mandal Dipak , Kumar Sanjiv , Tamin Muhammad , Yunos Khairil Anuar 
Published: September 2014

Abstract
The field in study has multiple stacked reservoirs with 10-20m oil column overlain by medium to large gas caps. PVT analysis from DST in the gas zones were available, which showed gas and condensate production at surface. Composition, PSAT and CCE data were available from surface samples. DST tests in oil zone provided only GORs, surface oil and gas gravities. Reservoir oil and gas gradients were also available from RFT/MDT.
The challenge was to generate representative PVT properties for the oil zone for reservoir simulation by integrating these partial datasets. Due to condensate production, it was necessary also to incorporate and characterize the vaporized oil fraction in the gas, which is not possible by using black oil correlations.
This paper describes the workflow used to integrate these partial datasets through an EOS model to generate representative PVT properties for the reservoir oil and gas. The composition from the gas cap sample was used to build an EOS Model which was tuned using CCE data and gas cap DST results. This partially tuned EOS was used to simulate a compositional gradient experiment which was tuned to match the PSAT at GOC obtained from RFT/MDT and equilibrium oil composition at reservoir temperature and pressure at GOC was calculated. This oil composition was then plugged back into the EOS Model and model was further tuned with reservoir oil density from RFT/MDT, oil API and production GOR from the oil zone DST. This tuned EOS was then used to export Live Oil and Live Gas PVT tables for simulation.
This approach helped to generate representative PVT tables which produced a good history match in the dynamic model within the range of uncertainty. This approach is now being tried with other reservoirs where PVT data is inadequate and is becoming helpful to tune PVT models.