bluuebunny/crossref_metadata_2025_split huggingface dataset:
Growth and Demise of Neogene Central Vietnamese Carbonate Platforms: The Effect of South China Sea-Opening and Onshore Uplift
Authors: Fyhn Michael B. , Nielsen Lars H. , Petersen Henrik I. 
Published: May 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Abstract
Neogene carbonate platforms cover as much as 70,000 km2 of the central Vietnamese South China Sea margin. The margin is little explored, and so far, exploration has focussed on Miocene carbonates with a number of oil and gas discoveries made. Carbonate growth initiated during the Early Miocene following Eocene-Oligocene continental rifting. Early carbonate deposition took place on two regional platforms separated by a narrow depression that marks the trail of the East Vietnamese Boundary Fault Zone (EVBFZ).
West of the EVBFZ, the Tuy Hoa Carbonate Platform fringes the Vietnamese margin between Da Nang and Nha Trang. In the west, platform growth initiated during the Early Miocene and continued until Middle Miocene time when regional uplift along the Vietnamese margin led to sub-aerial exposure and karstification. Seawards from the EVBFZ, carbonate deposition similarly commenced during Early Miocene time (Burdigalian). Platform growth took place on the Qui Nhon Ridge flanking the EVBFZ and farther seawards on the Triton Ridge. From the latest Early Miocene, stepwise partial drowning resulted in platform split-up and seaward retreat of carbonate growth. Hemipelagic drapes cap drowned platforms and indicate protracted periods of sediment starvation after drowning. Continued drowning is evidenced by platforms subcropping the present seafloor at few hundred meters depth, and modern platform growth only remains on a number of seafloor cuestas around the Paracel Islands far from the Vietnamese mainland.
The onset of widespread carbonate deposition largely reflects the opening of the South China Sea. The mid-Neogene shift in carbonate deposition is interpreted as a consequence of regional uplift of central and south Indochina starting around Middle Miocene time when the Qui Nhon Carbonate Platform became sub-aerially exposed. Stressed carbonate growth resulted from increased inorganic nutrient input derived from the uplifted mainland, which promoted platform drowning farther offshore.
Seismic Amplitude Loss Compensation for Future Reservoir Characterization Studies in Peciko Field - Indonesia
Authors: Brahmantio Rangga Andyaksa , Kusuma Andi Setia , Bertini Florent , Dufour Jocelyn , Paternoster Benoit Jacques , Leclair Simon 
Published: May 2016

Abstract
This paper describes a post-stack methodology to compensate the amplitude loss prior to commencing further seismic reservoir characterization studies in Peciko field. The available 3D seismic data shows that the high frequency part (25–55 Hz) of the seismic signal contributes more significantly to the variability of extracted wavelet amplitude than the low frequency part (5–25 Hz) and within the high frequency part, the amplitudes of the extracted wavelets correlate positively with the RMS amplitude of seismic traces from which the wavelets have been extracted.
This analysis led to the design and testing of a two-step amplitude correction scheme based on maps of RMS amplitude derived from the low and high frequency bands. The first step consists of locating the areas where the seismic signals require correction. The second step respects the defined correction area and uses specific gain maps for the low frequency and high frequency components. These corrections were optimized and controlled under the careful scrutiny of quantitative seismic-towell ties and attribute maps.
Application of the methodology has brought significant improvements to the initial seismic dataset, e.g. better preserved amplitudes, less variability of wavelet amplitude and enhanced seismic detection. All of these advantages were successfully obtained while barely influencing the background information. However, it has been shown that the relative added-value resulting from this approach will depend on the quality of the initial dataset itself. Heavily damaged amplitudes under massive shallow gas or anomalously low velocity features will probably be insufficiently compensated. In this perspective, careful control at many well locations and the mapping of QC attributes are very important to assess the method.
In our Peciko case, the compensated cube enables refinement of the previous interpretations and optimization of the development plan. Furthermore, these results motivated the application to the existing angle sub-stacks and opened the way to pre-stack seismic inversion for a more extensive reservoir characterization. This workflow has been applied to the other 3D datasets, such as Tunu and Bekapai 3D, which suffer from similar amplitude losses phenomena associated with carbonate or coal masking and shallow gas pockets.

Introduction

Geological Context
Peciko is a giant gas field and is located offshore in water depths of 30 to 50 meters, southwards of the modern Mahakam river delta and approximately 25 km to the South - East of the East Kalimantan coastal line. Peciko was discovered in 1983 and the field's gas accumulation is 20 km long by 10 km wide. The structure is a large nose dipping to the north-west with no fault identified (Figure 1a).
Assessment of Undiscovered Conventional Oil and Gas Resources of Thailand
Authors: Schenk Christopher J. 
Published: May 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Abstract
The U.S. Geological Survey estimated mean volumes of 1.6 billion barrels of undiscovered conventional oil and 17 trillion cubic feet of undiscovered conventional natural gas in three geologic provinces of Thailand using a geology-based methodology. Most of the undiscovered conventional oil and gas resource is estimated to be in the offshore Thai Basin Province.

Introduction
The U.S. Geological Survey (USGS) assessed the potential for undiscovered conventional oil and gas resources within 23 geologic provinces of southeast Asia as part of the USGS World Petroleum Resources Project (Schenk and others, 2010). This report summarizes the assessment of conventional resources in three provinces of Thailand—Khorat Plateau Province, Thai Basin Province, and Thai Cenozoic Basins Province (fig. 1). Prior to the assessment, the geologic framework and petroleum systems were developed for each province based mainly on published literature, which is extensive for petroleum systems in southeast Asia (for example, Todd and others, 1997; Doust and Sumner, 2007; Hall, 2009). Assessment units (AU) were defined within each petroleum system, and each AU was quantitatively assessed for undiscovered conventional oil and nonassociated gas accumulations (table 1). Co-product ratios were used to calculate the volumes of associated gas (gas in oil fields) and natural gas liquids. Exploration and discovery history was a critical part of the methodology used to estimate sizes and numbers of undiscovered oil and gas accumulations.
Sichuan Basin Shale Gas, China: Exploring the Lower Silurian Longmaxi Shale
Authors: Hackbarth Claudia , Soo Kwong Yin , Singh Navpreet 
Published: May 2016

Introduction
The Peoples Republic of China (PRC) has set ambitious targets to increase its domestic supply of clean-burning natural gas. Shale gas is one of the hottest exploration concepts in the global E&P industry, and according to press releases 2010–2011:• In 2010, the PRC Ministry of Land and Resources (MLR) set a target for the country to identify 50–80 shale gas prospects and 20–30 exploration and development blocks by 2020.• The Strategic Research Centre for Oil and Gas of MLR also set a goal to locate one trillion cubic metres of recoverable shale gas reserves, build 15–30 billion cubic metres of production capacity and produce 8–12 percent of China's natural gas from shale gas wells by 2020.• China National Petroleum Corporation (CNPC) announced a new shale gas research center. The center will focus on technology and equipment supporting shale gas exploration and development.• China and the United States announced the two nations would cooperate in several energy areas including shale gas development.• In addition to shale exploration already underway for own account, PetroChina signed an agreement for shale assessment with Royal Dutch Shell in November 2009 and Sinopec signed an agreement with Exxon Mobil in July 2011, for blocks in Sichuan Province and/or Chongqing Municipality.• In June 2011, auction tender results for four shale gas exploration blocks in Chongqing Municipality and Guizhou Province were announced. When the tender was originally announced in 2010, it was said that the successful Chinese companies would be able to form joint ventures with foreign partners to carry out the assessment if they so chose.
Shale gas exploration in China is already underway and rapidly increasing in activity level. The Sichuan Basin, one of the most prolific petroleum basins in China, is at the forefront. However, exploration and assessment of an untested shale gas play is typically lengthy and expensive. Compared to conventional oil and gas projects, shale gas projects may require a number of early wells to prove the existence and distribution of the gas, but then many more to test and optimize engineering techniques until a commercially viable combination is found. This process could be summarized into two over-arching questions: "Is there a material amount of gas?" and if yes, "Can it be produced economically?"
Geophysical Attributes to Improve the 3D Geopressures Prediction in HP/HT Environment
Authors: Cibin Patrizia , Mantovani Marco , Moglia Anna 
Published: May 2016

Abstract
The scope of the present work is to predict the pore pressure based on seismic attributes for an explorative well to be drilled in a complex area in terms of structural geology and pressure regimes.
Generally, the geopressures prediction is based on the correlation between seismic P-wave velocity and effective stress, but in the area under study this kind of relationship does not give reliable results. A different approach in analyzing the available data, based on an alternative methodology that uses the seismic inversion and the Vp/Vs ratio to predict a sudden increase of overpressure, is presented in this paper. Although a detailed interval velocity field was built using the Anisotropic Grid Tomography method, providing a good fit with the Vp Sonic log of a calibration well in the study area, the seismic/well velocities were not able to predict the abrupt increase of pore pressure near the Top Oligocene boundary with a single pressure regime. It was necessary to introduce two different pressure regimes above and below Top Oligocene in order to fit the measured pressure data. Even the Vs Sonic log did not show a significant deviation that could justify the pressure variations. However, when the Vp/Vs ratio was computed from Vp and Vs Sonic logs, a clear change in the trend was highlighted near the Top Oligocene boundary, partially confirming the presence of two different pressure regimes. In order to verify if these considerations could be extended to another prospect in the area, a Seismic Inversion study was performed around the proposed well location. Analyzing the Vp/Vs ratio volume resulting from the Seismic Inversion process, a similar trend was observed, confirming that an analogous behavior is present at the new location and a special attention is to be paid in the well planning and during the drilling operations.

Introduction
The knowledge of pore pressure using seismic data is useful in planning the drilling activity to control potentially dangerous abnormal pressures. Various rock physics conditions cause anomalous geopressure due to the formation fluids. Compaction disequilibrium is considered the main mechanism generating overpressures. It is activated when the sedimentation rate is so rapid that the pore fluid does not have the chance to 'escape' from the pore space. This phenomenon is often present during the very fast burial of shale layers, which have no time to expel the bounded water; with the increase of depth and temperature, the trapped water reaches pressure much higher in respect to the hydrostatic pressure, which may cause problems during the drilling activities. This is particularly critical in the explorative phases, when few geological and geophysical information are available and, generally, very sparse or no correlation wells are present. In these explorative areas, the seismic data are extensively used also to predict geopressures.
Advancements in Openhole Completion Technology - Establishing and Sustaining Differentiating Sand Control Completion Performance
Authors: Barry Mike D. , Hecker Michael Thomas , Yeh Charles S. , Moffett Tracy 
Published: May 2016

Abstract
Openhole completions are often selected as the preferred completion technique to maximize reservoir flow potential and provide reliable, high capacity, low skin completions. In many environments, these completions will also require some form of sand control. To meet development objectives, operators are continually challenged to select, design, and install fit-for-purpose completion strategies to optimize ultimate recovery for these fields. These challenges necessitated the creation of new practices, procedures, and hardware to ensure consistent delivery of reliable wellbores, across the entire organization, to achieve long-term, economic success.
ExxonMobil embarked on a multi-year initiative to establish and sustain a disciplined, systematic approach to sand control completion design, job execution, and performance assessment. The effort included the development, qualification, and deployment of selective, enabling completion technologies. Additionally, comprehensive engineering and operational guidelines, as well as, in-depth training were delivered to the worldwide engineering and operations workforce. Most significantly, the initiative is now resulting in effective and rapid transfer of learnings and best practices across the global organization. This comprehensive effort continues to focus on ensuring the right people are deploying the right technology in the right well.
This paper will discuss the guiding principles associated with our overall completion practices. It will also describe a number of enabling technologies pioneered by ExxonMobil including:• NAFPacSM, a gravel pack technique that allows the operator to run the gravel pack screens in non-aqueous fluid, gravel pack the well and displace the casing to brine, all in one trip• MazeFlo™, a self healing, redundant sand screen• Internal Shunt Alternate Path Technology (ISAPT) screens with openhole shunted packers, a completion technique that enables true and selective zonal isolation in openhole gravel pack applications

Introduction
Over the last 15 years, our industry has dramatically changed. The contrasts are remarkable. Just 15 years ago:• "Deepwater" was anything over 400 feet, not 4,000 feet• A high volume well made 3,000 bopd, not 30,000 bopd.• Completion intervals were hundreds of feet, not thousands.
Unquestionably, the development demands today are far more challenging than ever before. Wells are less accessible, have much higher drilling and completion costs and are more complicated to construct. Since fields are typically being developed with fewer wells, the overall productivity and longevity expectations of each and every completion can far exceed anything experienced in the past. As such, the ability to identify and capture the best completion practices and processes and then apply them systematically is a key step in maximizing resource value
Crosswell Seismic and Electromagnetics: New Advances in Interwell Imaging
Authors: Nalonnil Ajay , Zhang Ping , Marion Bruce P. , Phillips John G. , Dogra Sanjeev 
Published: May 2016

Abstract
Crosswell imaging as a concept and measurement technique for the oilfield has been maturing over the past two decades. As part of this development, both the seismic and electromagnetic versions of the measurement have seen recent advances that have allowed the technologies to answer more complex imaging requirements in the industry today. This paper features case studies which focus on the areas in which the methods have advanced, specifically; downhole seismic source, frequency attenuation tomography and indicator probability imaging.

Introduction

Crosswell Seismic Imaging
Crosswell seismic images the interwell space with an improved vertical resolution of up to 5–10 times higher than surface seismic data. Both direct and reflected wavefields are processed to provide a detailed image of the reservoir. By using higher frequency sources that are deployed alongside the reservoir interval, crosswell seismic surveying generates high vertical resolution reflection images with resolution on the order of 1–3 m. This is due to the high bandwidth of the transmitters used during acquisition with upper frequencies ranging from 800Hz to 2 kHz (depending on the transmitter used and imaging objective).
Since seismic velocity is very sensitive to pressure, temperature and saturation changes caused by the injection of CO2, gas, and steam, crosswell seismic provides valuable information for monitoring injection performance and efficiency as well as reservoir characterization. Crosswell seismic can reliably detect compressional wave velocity changes as small as 1–3%. (Lazaratos et al., 1997) Additionally, since the migrated reflection section provides a high-resolution image of the structure between wells, it helps in answering key questions about the geologic causes of the observed injection performance and fluid flow.

Crosswell Electromagnetics
Crosswell EM is a natural extension of the single well induction logging method whereby the transmitter and receiver are located in separate wells. This geometry provides high-resolution resistivity distribution of the subsurface between the wells. When obtained at different time steps during injection and production this resistivity distribution provides valuable information that can be integrated with other data to interpret the changes in the reservoir rock and fluid distribution between the wells. These data are valuable in updating the reservoir model with reduced uncertainty and enhanced predictability.
Resistivity is especially responsive to changes in fluid constitution in the reservoir and early work (Wilt et al., 1998) shows that it is also an excellent indicator of temperature related changes in the reservoir.
The Influence of Reservoir Rock Wettability on CO2-Foam Stability in Porous Media
Authors: Rafati Roozbeh , Hamidi Hossein 
Published: May 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Abstract
CO2 injection to produce more crude oil from the underground hydrocarbon reservoirs is one of the best methods to prevent the entry of this greenhouse gas into the atmosphere. Although the low viscosity and density of the gas create a viscous fingering and gravity override problems and reduce volumetric sweep efficiency of this process.
One of the most common methods to overcome these problems is the injection of stable aqueous foam as a mobility control agent into the underground reservoirs. Stability and strength of this kind of foam in porous media plays an important role in enhancement of the process efficiency.
Many published papers have been focused on the effects of both rock and fluid properties as key parameters of foam stability but research on the effects of critical parameters such as wettability of the porous medium, pore size and geometry remains incomplete.
In this study, foam stability was measured and compared in strongly water-wet, strongly oil-wet and mixed wet systems by using two-dimensional modified glass models. Alpha olefin sulfonate and Triton-100 were used as an anionic and nonionic foaming agent, respectively. The experimental results indicated that both foaming system presented higher stability in strongly oil-wet porous media than in strongly water-wet. It also illustrated that anionic surfactants have higher stability and mobility control performance in all water wet, oil wet and mixed wet systems.
Eventually, the experimental results showed that pore size and capillary forces are inversely related to foam stability in porous media. On the other hand, by reducing pore size, the capillary pressure increases and thus foam stability decreases inside the hydrocarbon reservoirs.
Development of Economical Gas-tight Casing Connection for Low Pressure Gas Field Application
Authors: Wang Jiandong , Yang Lineng , Song Shengyin , Yi Xiaoming , Li Dongfeng , Zhang Wei 
Published: May 2016

Abstract
Changqing Sulige gas field in China covers a large area of low pressure (reservoir pressure of less than 35 MPa) and low permeability reservoir. It was noted that the production rate per well has been low. Therefore, to increase the production efficiency, it was necessary to increase the number of wells to be drilled. As a result, casing connections became a large portion of the total cost of the field development. A low cost gas-tight casing connection would help to reduce the development cost in Sulige gas field. Primarily due to high cost, premium connections with dedicated shoulder and seal do not satisfy the economical development requirement. API long round threaded casing connections do not allow breakout after makeup with special thread compound (Catts101). Therefore, it is necessary to develop an economical casing connection with fast makeup feature and large bending and tensile load carrying capacity. Based on the finite element analysis, to improve the gas-tight seal performance with the API long round thread connection and buttress connection, a new type of casing connection was developed. The new casing connection has modified radii of the crest and root of the thread with wider ridge than groove to ensure full contact of the load flank and stab flank of the internal and external threads upon makeup. In addition, the thread crest and root are separate to prevent galling. The internal thread on the box has varying taper at the makeup location to enable gas-tight seal upon makeup with the last thread on the pin. Nonlinear finite element analysis of this new connection design (139.7×9.17mm N80) showed the new design with a clearance of crest and root with surface coating on box at the engaged gas-tight seal position, combined with the make-up and tensile load carrying capacity of 80% material yield, can meet low pressure (60 MPa) gas seal. This new casing connection design was verified with full-scale testing to ensure the successful application in Sulige gas field. Contrary to other premium connections, this new casing connection has no dedicated seal and shoulder regions and relies on the last thread for sealing. Such design has several advantages, such as low cost, low material consumption, easy for QC, no requirement for special thread compound and easy for make-break. It satisfies the requirement of economical development of low pressure and low permeable gas field.