bluuebunny/crossref_metadata_2025_split huggingface dataset:
Recent Advanced Applications of Formation Testing in Daqing Oil Field Aiding Field Development
Authors: Wu SX. , Chen ZF. , Chen J. , Xian C. 
Published: May 2016

Extended Abstract
This paper is to summarize the advanced applications of formation testing in Daqing field in recent years and to share the experience on how to use formation testing technology to improve field development plan adjustment by understanding better the water movement and EOR fluid front distribution using formation testing technology.
Daqing Oil field is the most critical oil field in China to supply stable oil production for Chinese domestic demands. It involves continue exploring of new reserve in more and more challenging formation and continue pushing for higher oil recovery by fine turn water injection strategy and utilizing leading edge EOR technology. In order to achieve this objective, the latest formation testing technology has always been evaluated and applied in Daqing development field in last 10 years. Tons of pressure and fluid data has been collected to in such an efficient and cost-effective approach.
Other than fluid typing and obtaining fluid samples in exploration wells, the conventional formation testing applications, formation testing has been used more in development field in Daqing field recently to understand water movement helping defining infill drilling plan and in EOR stage, to understand EOR fluid front. This helps the field operator greatly to figure out the potential of a mature field and maintain stable production ultimately.
Measuring and Profiling Casing Corrosion for Predicting Subsurface Leaks
Authors: Al-Yateem K.S. , Kohring J.J. , Qahtani H.B. , Garcia J. 
Published: May 2016

Abstract
Locating downhole casing leaks in producer and injector wells is not a complex undertaking when using rig-operated straddle packers with pressure testing. However, this established technique has limited effectiveness because it does not necessarily address the overall comprehensive integrity of the entire completion, which might include additional intervals of serious corrosion leading to leaks in the near future.
We examined the results of low-frequency electromagnetic (EM) remote frequency eddy current (RFEC) wireline logs from over 80 wells in one mature Middle Eastern offshore field, profiling the severity of measured metal loss (ML) from concentric casings against proven rig-discovered leaks and rigless measurements of subsurface ML. Casing leaks that otherwise would have been detected only by conventional zonal pressure testing from a workover rig can now be located and forecasted with a high degree of probability when using this evaluation tool.
The importance of maintaining oilfield casing integrity for safety, environmental, and flow assurance objectives, combined with the high costs of drilling new wells, creates a necessity for this integrated well integrity appraisal approach. Application of this EM logging technology to identify intervals of external ML has great significance in being able to anticipate casing intervals with high likelihood of failure due to invasive corrosion.
Application of Nozzle-Based Inflow Control Devices (ICD) in AL- Khafji Field
Authors: Abd Elfattah Mahmoud , Gottumukkala Varma , Sadah Ahmed Alawi Ahmed , Mohamed Tawakol I. , Nufaili Subhi Ali 
Published: May 2016

Abstract
Al-Khafji field, located in the Arabian Gulf, contains an unconsolidated sand reservoir subdivided into two reservoirs (A and B). The main obstacle in Al-Khafji field is water encroachment due to unfavorably high-water mobility compared to oil; therefore, the field presents a reservoir management challenge in the form of curbing water production in these relatively high-permeability sandstone reservoirs. Both reservoirs (A and B) have irregular water-front movement and water encroachment is dominated by edge-water drive for reservoir A and bottom water drive for reservoir B. Water coning/fingering problems are evident even in the crestal regions. This water encroachment problem can be explained by one or combination of:Water movement behind casingWater movement along conductive fault planes
Typical Al-Khafji field horizontal wells are completed with cemented liners and perforations. The wells typically water out during the initial production phase because of the reasons explained previously and limitations on surface water handling capabilities adds to the problem by preventing the wells from flowing at their full potential.
A new technology for horizontal well completions has been proposed by integrating 350-µm screens with inflow control devices (ICD) and packers to curb the water production by delaying water breakthrough and managing sand production. Numerous wells in the field have been completed with a nozzle-based ICD, and the promising results will be discussed during the course of the paper.
The ICD-completed wells will be analyzed and compared with nonICD-offset wells. The parameters that were used during the ICD-completion design to overcome the main field challenges will be highlighted. Completion strategy has been changed in Al-Khafji field based on positive performance results from the ICD-completed wells.
Enhancing Drilling Safety Performance Through Effective Communication Culture
Authors: Boucif Mustapha Nasreddine , Al Mutawa Ahmed 
Published: May 2016

Abstract
There is no way to obtain zero injuries in any organization without the commitment of the workforce. This article will show how Abu Dhabi Company for Onshore Oil Operations (ADCO) Drilling Division and its contractors obtained employee commitment resulting in world class performance in HSE for the past five years and recorded the lowest Total Recordable Injury Rate (TRIR), the second lowest Lost Time Injury Frequency (LTIF) in ADCO's Drilling Division history and the longest time without LTI (Eighteen months without LTI) in 2011. In addition we have recorded zero car related injuries for the past four years and zero spills in 2011.
DOIRC (Drilling Operations Incident Review Committee), a monthly meeting with all our contractors was a key factor in improving the safety performance of the drilling community by developing 360° communication between ADCO main office, ADCO field, Contractor's management office and their teams in the field. The forum also have shifted from a reactive committee where only incidents are discussed to a proactive forum where best practices are shared and a communication network was established to inform the fields on regular basis.
In addition to that, High Profile Tours (rig visits by ADCO Top Management), DOIRC High Profile Tours (rig visits by ADCO and contractors Top Management), onsite workshops and regularly launching campaigns with our drilling contractor National Drilling Company (NDC) were the additional tools used to raise Drilling Division performance to a world class performance.
ADCO Drilling Division has clearly established a successful formula for its safety performance to reach and maintain a world class performance for the past four years, reaching 0.52 TRIR in 2011 and 0.09 LTIF in 2008 and 2010;the lowest in ADCO Drilling history through effective communication culture.
Production Forecasting and Analysis for Unconventional Resources
Authors: Zhou Wentao , Gupta Siddhartha , Banerjee Raj , Poe Bobby , Spath Jeff , Thambynayagam Michael 
Published: May 2016

Abstract
Horizontal well drilling with multistage fracturing technology has been the common practice to develop unconventional resources. During the development of such resources, we are often faced with the following questions: How can we optimize the stimulation treatment? How much can the well produce? What are the production data telling us? Answering these questions requires technologies and tools to be able to forecast and analyze the production behavior of fractured wells.
We investigate the physics and mathematics involved in production forecasts of both planar fractures and fracture networks that are generated due to stress isotropy and pre-existing natural fractures. We use analytical methods because they give rigorous yet very fast solutions. Since simulation expertise is not required to use our model, it is an accessible tool for multiple disciplines. A new nodal analysis approach is proposed for unconventional resources.
Production forecasting enables the optimization of a well stimulation treatment, and helps to determine, for example, the number of fracture stages and the amount of proppant to use. Case studies illustrate the concept and some of the practical aspects of fractured well production, such as the impact of propped conductivity and unpropped conductivity.
The composite workflow for diagnosis and analysis of production data specific to unconventional resources was applied to real case examples. The workflow involves flow regime identification, decline curve analysis, and rate transient analysis. The workflow is easily scaled from single-well level to well clusters to full field implementation.
Construction and Operation of HPHT Pipelines Designed for Lateral Buckling in the South China Sea
Authors: Ramaiah N. , Bong A. 
Published: May 2016

Abstract
Gas production in the South China Sea has seen increasing trend of pipelines operating in HPHT (high pressure and high temperature) condition. This has led operators to stretch beyond the conventional stress-based design and move into strain-based design using the lateral buckling design approach. In previous article by Nils Kristiansen et al [1] and paper by Lim Kok Kien et al [2], the lateral buckling design methodology and initiation method were discussed and verified against field data. This paper presents both construction challenges and operational works following post start-up. Construction cost benefits for proven initiation method and actual laboratory data resulting from material testing for the purpose of welding acceptance criteria are included in this discussion. Routine maintenance practices, engineering post start-up and operating envelope developed for pipeline designed for lateral buckling will also be discussed. The intent is to provide operators with cost effective construction solutions and risk-based maintenance philosophy when considering lateral buckling design.

Introduction
Increasing temperature and pressure in gas production has led some operators to stretch beyond the conventional stress-based design for pipelines. One of the methodologies to address HPHT condition is the state-of-the-art lateral buckling design. Lateral buckling design is a strain-based design that allows the pipeline to expand laterally at designated locations in a controlled manner. This allows the pipeline to relieve its thermal expansion by lateral movement rather than being axially restrained (i.e through trenching and burial).
As with any non-conventional methodology, such design has certain limit states which require careful consideration. The limit states are local buckling, low cycle fatigue, fracture and pipeline walking. These limit states are addressed during the design phase except for fracture; which is addressed during construction phase. During operation, these limit states are also monitored periodically to ensure that the design thresholds are not exceeded.
A New Calculation Method for Single Well Controlled Dynamic Reserves of Tight Gas
Authors: Zhenhua Cai , Xinwei Liao 
Published: May 2016

Abstract
Tight gas features with low permeability and process of flow is complex. Gas well production is based on dynamic reserves. The traditional methods include volumetric method and material balance formula which uses the shut-in pressure measurement data to calculate the dynamic reserves. This paper raises a new method to calculate dynamic reserves with BHP. The advantage is with no need for shutting well and compared to well-test, the result is accurate.

Introduction
The tight san gas is one type of unconventional, has ultra-low permeability. If without enhance treatment, can't get industrial flow. So enhance treatment is necessary. The boundary of tight gas is dynamic therefore well controlled reserve is dynamic as well. Conventional method for reserve calculation of gas reservoir include Volumetric method, material balance etc. Volumetric method is applied of static reserve and material balance need formation average pressure which is difficult to measure. For poor connectivity, it takes couple month even year for well shut to gauge formation pressure Pr. Shutting well for long time cause huge lost for production unit. The method presented in this paper gains dynamic reserve without gauge Pr, and approved by real example.
Characterizing Fluid Distribution in Highly Compartmental Chinese Oilfield by Advanced Cased-Hole Formation Testing
Authors: Ma J. , Yu H. , Wang Y. , Xian C. , Yang L. , Fu L. , Chen J. 
Published: May 2016

Abstract
Yingdong oilfield in West China is one of the biggest discoveries recently in china land with probable reserve estimated to be over 100 million tons oil equivalent. This field is small in area coving around 8.1 km2 only. But the oil column is over 400 meters in one of the exploration well and distributed in more than 100 sand zones. Recent seismic work reveals that this reservoir is extremely complex on structure due to the faulty nature. As the consequence of this, significant reservoir compartmentalization is expected and proved by newly drilled appraisal wells. Two wells with only a few hundred meters distance demonstrate completely different hydrocarbon water system. Thus understanding the type of fluid and its distribution becomes the biggest challenge for Yingdong field appraisal and planning the field development in the near future. And testing all these thin zones becomes impractical considering the cost and the time constrains.
A recent project of using Cased-Hole Formation Tester to characterize the fluid type and distribution in three wells in this field was accomplished with great success. 20 zones were carefully selected in three critical wells and tested within one-month time. Besides obtaining high quality fluid samples, the hydrocarbon properties, (GOR, composition, bubble/dew point, etc) are also evaluated in real time with the latest downhole fluid analysis technology. It provides timely input to the current production pilot work. The log interpretation results have been revised in quite a few zones with this formation testing answers also.
The Indicator Diagram Collection Based on the Beam Pumping Unit Motor Effective Power Measurement
Authors: Guo Yueming , Ma Liang 
Published: May 2016

Abstract
Conventional beam pumping unit is the most popular lifting equipment at well site, especially in mechanical oil production. To identify its operation, the indicator diagram is an effective tool. Therefore, study on indicator diagram measuring methods has been made as a key subject in major oilfields in China. Currently, force sensors and displacement sensors are commonly used to measure the polished rod load and displacement, so as to generate the indicator diagram. The force sensor is always exposed to the compression and tension of alternating loads, which will damage its elastic coefficient, finally leading to less-precision or even invalid measurements. Besides, this application may bring challenges in installation of devices, work life of the sensors, maintenance and operating cost, which will affect the analysis of well conditions. In summary, the technique cannot satisfy the current requirement of digitalized well management.
In view of above issues, this paper proposes a new measurement method. The useful motor power of the beam pumping unit is acquired in real-time manner, and based upon the law of conservation of energy, the motion pattern of the unit is analyzed, to establish a mathematical model containing useful motor power, polished rod load and polished rod displacement. The model can figure out the relationship between beam pumping unit output power and load. Then, in line with field physical calibration, the indicator diagram is measured. This method doesn't require complex installations on the site. Instead, only electric parameters for input and useful power, apparent power and power factor are acquired to determine the actual polished rod load, according to the correlation between power of the unit and load. Finally, the indicator diagram of the pumping unit is measured indirectly. This method can greatly contribute to the site installation efficiency, work lift of measuring devices and measurement accuracy.
This method has been tested in 20 pumping wells. It is found that the equivalent indicator diagram illustrates accordant tendency with the measured indicator diagram; average relative error of area is less than 8%, and average relative errors of maximum and minimum loads after calibration are not greater than 10%. These suggest that the equivalent indicator diagram reconcile with the measured one, and can be used in real time monitoring of pumping well conditions by using useful motor power data. This technology has been effectively applied in an oilfield domestically.
The Awakened Giants
Authors: Abdullah Che Shaari B , Mohamad Khazali Nur Fadzlinda Bt 
Published: May 2016

Introduction
Since late 1960's, there are intensive exploration activities conducted off the coast of the state of Sarawak, Malaysia. The offshore region to the northwest of Borneo Island saw a heightened state of exploration activities for hydrocarbon following increasing demand for fossil fuel as a result of world industrialization. Miocene carbonate pinnacles are one of the target play types identified and chased within the Central Luconia geologic region. In those days the more obvious, mega size shallow carbonate build-ups which are considered as the "low laying fruits" became the first priority exploration test candidates. Some of the pinnacle build-ups are proven gas fields with few of them classified as "giant class" accumulations (Figure 1). Nevertheless, a lower than expected overall exploration success statistical trend coupled with low priority in the business strategy for gaseous hydrocarbon further compounded the issues which arrested the exploration initiatives. A "hiatus" in exploration activities ensued beginning in 1980's. On the subsurface side, geologic assessments then identified hydraulic seal failure and "thief sand" as the probable contributing factors in the unsuccessful cases. Extremely high aquifer pressure combined with the hydrocarbon buoyancy effects thought to have breached the cap seal mechanical strength which caused capillary hydrocarbon leakages. The presence of post carbonate permeable sandy formation down lapping onto the pinnacle is the other identified geologic risk element. Inter-fingering of the sand and carbonate introduced leak point which provided drainage conduit diverting the hydrocarbon away. The incriminating "blown trap" theory was thence adopted loosely as an explanation to the situation. On the other hand apparent deeply buried pinnacles are intuitively associated with high formation pressure, temperature and non-hydrocarbon gas contaminants further added up the situation complexity. The anticipated drilling operation complications from such conditions are henceforth associated with potential high costs. These conditions summed up have led to premature condemnation of the remaining carbonate pinnacle play type potential in the region. There was absolutely no interest to further realize the hydrocarbon potential of the pinnacles since then.
Recent works within the region re-evaluating the similar pinnacles have proved the contrary. The pre-conceived misconceptions of the play types were rectified and adoption of the findings proved very rewarding conclusions.
Materials and Corrosion in LNG Industry - Our Experiences
Authors: Murty J. V. D. , Muzghi Ibrahim A. 
Published: May 2016

1.ABSTRACT
Liquefied Natural Gas (LNG) industry utilizes a variety of materials to serve its needs in diverse service conditions, from cryogenic to moderately high temp applications, to a multiplicity of corrosive environments. The content of the submission is applicable all across the LNG industry.
This paper focuses on the applications and materials used by Qatargas for LNG production, at both onshore and offshore facilities. It examines mechanical and metallurgical concerns with emphasis on areas of corrosion and the solutions devised to address these items of interest. The presentation discusses in detail case studies and Qatargas experience in selection of materials, metallurgical problems faced and their failure mechanisms such as graphitization, sigma phase formation etc.; mechanical in nature such as vibration induced fatigue etc.; corrosion in nature such as crevice corrosion, environmental assisted cracking, flow accelerated corrosion, aggressive environmental corrosion etc. and solutions arrived for each of the cases.
These case studies will be supported by data, analysis, with photographs and other relevant facts and figures for reference as well as details of solutions and remedial measures implemented for each of the cases.
As subject matter of the presentation presents case studies of problems faced and solutions reached, the information will be directly applicable to similar service conditions and will be of direct significance to LNG industry.

2.INTRODUCTION LNG INDUSTRY
The share of Natural gas in the basket of different types of raw energy produced around the world is growing. No doubt, Natural gas from conventional gas reservoirs is the major source of supply, though shale gas, coal-bed methane etc. are proving to be promising developments. Meanwhile, the growing need for cleaner power production is driving major fast growing economies such as China, India and South Americas to invest in more natural gas-burning power plants. The low price of gas as a result of a gas glut in the US is making gas a more competitive source of power than oil and renewable energy technologies such as wind and solar power.