bluuebunny/crossref_metadata_2025_split huggingface dataset:
An Attractive Raw Deal – Novel Approach to Barton Oilfield Water Injection
Authors: Lee Steven Kiong-Hooi , Tan Thiam-Guan , Vaughan Andrew 
Published: December 2007

Abstract
This paper describes the integrated subsurface/surface concept generation and challenge process which delivered a novel water flood project (raw seawater injection), slashing 60% off the original engineering Capex, while still addressing key subsurface uncertainties, and keeping within the normal project timescale. It also attempts to identify the key factors and processes that helped to deliver this innovative solution in spite of the challenges.
The processes described in this paper allow for early surface/subsurface/well engineering engagement in order to promote creativity and manage uncertainties in challenging E&P projects. Managing such creative, parallel processes has allowed the Barton team to be better integrated in finding an optimal and novel solution to a complex situation, hence positioned to deliver higher value within a reasonable timescale. The team acknowledges the value of a structured process to generate widely divergent solutions (which look like chaos at the time), and the creative tensions and discomfort that accompany shifting through this chaos to deliver an innovative solution. It also described the means in which the team had built stakeholder support for new ideas through engaging global expertise.
Experimental Design and Analysis Methods in Multiple Deterministic Modelling for Quantifying Hydrocarbon In-Place Probability Distribution Curve
Authors: Peng Cheong Yaw , Gupta Ritu 
Published: December 2007

AbstractThis study addresses a few issues regarding the experimental design and analysis (EDA) methods, and its applications in multiple deterministic modelling to quantify hydrocarbon in-place (HCIIP) probability distribution curves. They include (1) the suitability of using Latin Hypercube design (more than 3 levels in the input variables) compared with the 3-level fractional factorial designs (FFD) (e.g. 2k-p FFD with centre & axial runs); (2) multidimensional kriging versus response surface method as the analysis technique to fit surrogate equation models; (3) the selection of test runs to evaluate the fitted surrogate equation models; (4) sensitivity of the assigned input probability values on the output response distribution curve; (5) the confidence interval of the cumulative probability distribution curve at median (P50) or other percentiles (e.g. P10 & P90); and (6) how to select representative 3D geological models at P10, P50 and P90.In this study, an Excel spreadsheet, which mimics the 3D geological modelling workflow to estimate the oil in-place volume, is used to compare the above mentioned designs and analysis techniques. Some guidelines to select representative test runs/models to evaluate the fitted surrogate equation models are discussed. In multiple deterministic modelling, all the input uncertainties will normally be quantified with an uncertainty range from low, base to high values, and with their assigned probability values. Then, a decision tree can be built to visualise the full range of all the possible 3D geological models, and their respective probability of occurrence can be calculated from the probability of the input uncertainties. Combining the probability and the predicted responses from the evaluated surrogate equation model, the output response (e.g. oil in-place) probability distribution curve can then be built. Sensitivity of the input probability values on the output response distribution curve is briefly discussed. There will be some errors associated with the predictions from the surrogate equation models, and therefore confidence interval must be generated to account for them. With the P10, P50 and P90 output response values, the confidence intervals and the probability of occurrence, some representative 3D geological models at P10, P50 and P90 can be selected.A 3D multiple deterministic modelling case study is then used to demonstrate the methodology in estimating the oil in-place distribution curve of a synthetic reservoir that is adopted from an actual fluvial reservoir.In conclusions, the EDA methods can be used to minimise the number of 3D geological models that must be generated to build good HCIIP probability distribution curves. By using bootstrapping and normal confidence interval, fitting errors can be quantified and representative 3D geological models for P10, P50 and P90 values can be selected accordingly.
Digital Core Laboratory: Properties of Reservoir Core Derived from 3D Images
Authors: Knackstedt M. A. , Arns C. H. , Limaye A. , Sakellariou A. , Senden T. J. , Sheppard A. P. , Sok R. M. , Pinczewski W. V. , Bunn G. F. 
Published: December 2007

Abstract
A facility for digital imaging, visualizing and calculation of reservoir rock properties in three dimensions (3D) is described. The facility includes a high resolution X-ray micro-computed tomography system capable of acquiring 3D images made up of 20003 voxels on core plugs up to 5 cm diameter with resolutions down to 2 µm. Subsets of four sandstone reservoir core plugs (5 mm in diameter) from a single well of a producing gas field are imaged in this study. The four cores exhibit a broad range of pore and grain sizes, porosity, permeability and mineralogy. Computational results made directly on the digitized tomographic images are presented for the pore size distribution, permeability, formation factor, NMR response and drainage capillary pressure. We show that data across a range of porosity can be computed from the suite of 5 mm plugs. Computations of permeability, formation factor and drainage capillary pressure are compared to data from a comprehensive SCAL laboratory study on 70 cores from the same well. The results are in good agreement. Empirical correlations between permeability and other petrophysical parameters are made and compared to common correlations. The results demonstrate the potential to predict petrophysical properties from core material not suited for laboratory testing (e.g., drill cuttings, sidewall core or damaged core) and the feasibility of combining digitized images with numerical calculations to predict properties and derive correlations for individual reservoir rock lithologies.
Exploration Applications of Downhole Measurement of Crude Oil Composition and Fluorescence
Authors: Betancourt Soraya S. , Fujisawa Go , Mullins Oliver C. , Eriksen Kare Otto , Dong Chengli , Pop Julian , Carnegie Andrew 
Published: December 2007

Abstract
In addition to geological and petrophysical data acquisition during the exploration stage, in-situ fluid analysis provides a wealth of information for the appraisal of new discoveries. A recently introduced wireline sampling tool incorporating a downhole fluid analyzer is capable of analyzing fluid composition in real time at downhole conditions, and of measuring the fluorescence spectra of crude oils. These new measurements provide valuable information necessary for the identification and validation of reservoir structures that define the distribution of fluids in the accumulation. The relevance of high quality fluid data in the early stages of the producing life of the reservoir is widely recognized. We present field results of the application of the new sampling tool in an exploration well, where a composition gradient was detected along a 30m liquid hydrocarbon column grading from a 45API crude on the top to a 33API crude on the bottom. During the sampling of the gas cap, retrograde dew formation was detected identifying the fluid and identifying valid sampling conditions. This new information was used to modify the sampling program. Fluid composition analysis relies on optical absorption methods and is currently capable of providing the mass fraction of three hydrocarbon molecular groups: C1, C2-5 and C6+, and CO2. We perform fluorescence spectroscopy by measuring light emission in the green and red ranges of the spectrum after excitation with blue light. Fluorescence in this range is related to the concentration of polycyclic aromatic hydrocarbons (PAH’s) in the crude oil. Using the pump-out module to segregate different fluid phase enhances phase detection with fluorescence.
Methodology and Applications of A Multidisciplinary Reservoir Engineering Study for the Mature Oilfield
Authors: He Liu , Han Hongxue , Qunyi Wang 
Published: December 2007

Abstract
This article introduces the background and the methodology of a multidisciplinary reservoir engineering study that was carried out in Daqing Oilfield. The article focuses on the late stage of high water cut period multidisciplinary reservoir engineering study and the results of field application. The actual field application effectively improved the oilfield development and increased the recovery ratio.
A Workflow Approach to Life of Field Management
Authors: Yeow Lei-Ming , Nor Rosly Mohd , Lee Boo-Soon , Tsen Kin-Wei 
Published: December 2007

Abstract
Effective management of oil and gas fields over field life with the objective of maximising asset value can be a complex affair. Application and integration of various skills from subsurface (geology, geophysics, petrophysics, reservoir engineering, production technology and drilling) to surface engineering, production operations / surveillance and economics disciplines are required to manage technical, commercial and political challenges and uncertainties. In large organizations, there are the additional challenges of ensuring consistent work quality and process with multiple projects and technical personnel with different levels of skills and experience.
Subsurface and economic disciplines workflow over a field life from acquisition of exploration or development areas, exploration, development, production and abandonment work activities were mapped, improved and integrated to ensure work are executed more efficiently and correctly.
This paper describes the techniques and activities involved in developing this workflow which incorporates data and information management, technology mastery and promoting a collaborative and integrated multidiscipline approach. It was developed and deployed in two phases over 3 years and became the first web enabled workflow in the organisation. Pilot implementation was carried out on a number of domestic, international and outsource Field Development and Field Review projects.
Case histories of the application, benefits gained and lessons learnt are discussed this paper.
A Production Benefit Evaluation Program
Authors: Tang Wei , Zhang GuangJie , Sun JiPing , Chen YuHan , Guo FuJun , Xu Yan 
Published: December 2007

Abstract
Since 1998, we have launched a production benefit evaluation program at all 13 oil provinces. By classifying oil production according to benefit levels, we try to establish the concept of economic production and set the reasonable production target on the basis of economic benefit.
This paper describes the method of production benefit evaluation in detail. This production benefit evaluation program consists of developed oilfield evaluation and individual oil well evaluation. There are strict and detailed regulations on division of evaluation unit (for developed oilfields), selection of evaluation parameter and amortization of expenses. Also we introduce the progress of the production benefit evaluation program, evaluation results and its application.
Through this program, we get a good idea of the distribution of oil production in different benefit ranges and the status of operating cost. By taking adjustment measures, the operating cost of evaluation production have reduced greatly. As a practice of our low-cost strategy, this program is of great significance for controlling operating cost and enhancing economic benefit.
A Study on the Modelling of Knowledge Value Chain
Authors: Chen Yeong-Long , Yang Tzer-Chyun , Lin Zsay-Shing 
Published: December 2007

Abstract
The purpose of this study was to develop and apply a knowledge value chain (KVC) model. The model is based on Drucker's next society, Porter's value chain, Nonaka's spiral of knowledge, Kaplan and Norton's balanced scorecard, Gardner's multiple intelligences, and Pareto's 80/20 rule. An optimization technique is included in the model to identify the nodes (individual employees or groups of employees) of the critical value chain (CVC) and optimum value chain (OVC). The KVC model includes a business phase and a numerical phase composed of input knowledge, knowledge activities, and output goals. The input knowledge can come from intranet, extranet, and Internet channels and can be tacit and explicit. Whatever the source, input knowledge will converge toward an enterprise information portal (EIP). The value- added knowledge activities are based on socialization, externalization, combination, and internalization of knowledge. The knowledge value chain can be determined from output goals based on selected multiple values.
We applied the KVC model when analyzing employee value contributions at K Company in Taiwan. We selected five values (goals): customer, financial, learning and growth, internal business process, and innovation. The results of our application of the KVC model offered three key findings. First, the strengths and weaknesses of each employee's core competence were examined. Second, the critical nodes (winners' nodes or those of high-performance employees) for each goal were detected, and the selected critical nodes were gathered together to share their best practices. Third, optimum goals to reach the maximum value contribution to K Company were calculated.
Development and Implementation of Risk Based Inspection Methodology in Managing Inspection of Pressurized Production Facilities
Authors: Dewanto Kusmaryanto , Christian Rommy , Wibowo Ricky 
Published: December 2007

Abstract
VICO Indonesia operates in Sanga-Sanga, East Kalimantan produce gas and oil with approximately 1.0 BSCFD and 30,000 BOPD in 5 main plants; Badak, Nilam, Semberah, Mutiara, and Pamaguan. VICO Indonesia is continuously encouraged to reduce operating costs by minimizing operations cost and optimizing operability. One of the strategies is using Risk based approach methodology in carrying out inspection management for pressurized production facility. The objective of risk-based inspection is to ensure and maintain the required confidence of pressurized production facilities and maximizes its operating availability by planning of inspection interval and methods.
The basic steps of risk-based inspection are: –Creation and maintenance of asset register–Assessment of consequence and probability of failure–Creation inspection planning–Evaluate the inspection results–Review by risk based "team approach"
The feedback loop of risk-based inspection is essential for the continuous improvement.
This paper summarizes the experience in developing and implementing risk based inspection strategy for tackling the most failure mode in VICO Indonesia's pressurized surface production facilities. A description is given on how to focus inspection resources using risk based "team approach" involving inspection, operation and process engineers. A challenge of obtaining a reliable and cost effective inspection technique is also described. Finally, some useful lesson learned are included to prevent common problems from recurring, to stimulate the application of better practice and where possible to prevent or reduce the failure.
The Arun Gas Field in Indonesia: Resource Management of a Mature Field
Authors: Pathak Prabodh , Fidra Yan , Avida Hanifatu , Kahar Zulkarnain , Agnew Mark , Hidayat Dodi 
Published: December 2007

Abstract
The Arun gas field is a giant hydrocarbon resource in Indonesia and has been supporting Liquified Natural Gas (LNG) sales to the Asian market since 1978. The ultimate gas recovery is expected to be about 94% of initial gas in place, and the ultimate condensate recovery is expected to be a very high 87% of initial condensate in place. As the field has matured, reservoir pressure has declined and well productivities have declined. Mechanical wellbore failures have increased because of increased downhole stresses.The lower reservoir pressure has also increased the water vapor content in the gas, and producing wells have started to loadup as flow rates have decreased.
The application of new technologies has generated numerous opportunities to extend field life. Recent work has focused at maintaining productivity despite declining reservoir pressures. This paper presents a summary of Arun history and examples of recent resource management practices, including compression upgrades to reduce wellhead pressures, under-balanced drilling into a pressure-depleted reservoir and problem well restarts.
Challenges in Oil Production Technologies Affecting the Sustainable Development of Daqing Oilfield
Authors: Liu He , Yan Jianwen , Wang Qunyi , Sun Xishou 
Published: December 2007

Abstract
The paper introduces some problems that subdivision injection and production technology is facing in the stage of extra-high water cut production in Daqing Oilfield, the problems have become main factors affecting sustained development of Daqing Oilfield, like subdivision water injection, separate layer fracturing in thin restraining barrier and injecting surfactant to reduce pressure problem, each of them is close to challenge technical limit.
Formation Pressure Testing In the Dynamic Drilling Environment
Authors: Proett Mark , Fogal Jim , Welshans David , Gray Charlie 
Published: December 2007

Abstract
This paper introduces a new technology in which a logging while drilling (LWD) tool is used to pressure test a formation during the drilling process. The Formation Testing While Drilling (FTWD) or GeoTAP* tool described in this paper uses a testing technique similar to wireline formation testers. A probe is extended to the formation and a small sample chamber is used to pressure test the formation. The drilling environment offers many new challenges to pressure testing, however.
Wireline tools require a great deal of interaction with the engineer, which is very limited in the drilling environment. Therefore, the new tool has up-link and down-link capabilities and is highly automated for test control. New data compression routines are described that enable not only some of the raw data to be transmitted, but formation permeability (mobility) and test quality estimates to be obtained in real-time. An efficient algorithm is used down-hole to analyze the data where testing parameters and selected pressure data are transmitted to the surface in real-time for continuous monitoring of the test.
The drilling environment is more dynamic than is the case for wireline testers. Pressures in the borehole are constantly changing due to several factors. Invasion and the resultant supercharge effect can affect FTWD measurements. Supercharging results from mud filtrate invasion increasing the sandface pressure just behind the mudcake. Additionally it is desirable to keep the mud pumps on while testing to avoid hole deterioration and pipe sticking. Slower hydrostatic pressure changes can also occur due to drill pipe movement causing a swabbing effect. These pressure transients can be transmitted through the mudcake and into the formation. Using a newly developed near wellbore model that considers mudcake properties and invasion, these effects are simulated. A sensitivity study demonstrates the conditions that affect the stability and accuracy of the FTWD measurements.
Field data from the new GeoTAP tool are presented and compared with wireline formation test (WFT) data in test wells. The new tool requires the drill pipe to stop rotating/sliding for about 7 minutes per pressure test. During this time the pumps can be turned on or off. Most of the test results were taken with the pumps on. A "pumps on" GeoTAP tool field example is also presented, and the results compared very favorably with WFT data in terms of the absolute pressure measurement, repeatability and accuracy. The field example demonstrates the robustness of the measurement with three repeat pressure tests that were taken at three different depth points where, in each case, the pressures recorded were within 1 psi. Final conclusions are drawn regarding FTWD technology and its future direction.
Application of New Impregnated Diamond Bit Technology Saves Operator $2 Million Drilling Southern Oklahoma Well
Authors: West W. Cory , Roy Bryan J. , Knowles Steven P. , Wiesner Brian C. , Isbell Matthew R. 
Published: December 2007

Abstract
Economic development of deep gas wells, such wells in the Carter-Knox field in Stephens and Grady Counties, Oklahoma, depends on the effectiveness and efficiency of the drilling program. Many costly challenges are encountered while drilling the deep, high compressive strength, abrasive sandstone and interbedded shale in this geologically complex area with high-angle beds, faults, fractures, and depleted formation pressures. Improvements in bit technology have expanded the variety of formations that can be drilled with impregnated bits at penetration rates equivalent to roller cone bits. This technology has helped reduce the risk in drilling operations while improving well economics.
A recent well in the Carter-Knox field utilized three new impregnated bits to drill the interval from the third Bromide sandstone (15,000 ft) through the Arbuckle limestone and dolomite (18,700 ft) in 51 days improving well construction time by 35% over the best offset. Previous offset wells required 18 to 20 roller cone, natural diamond and traditional impregnated bits to drill the same interval in 78 to 155 days. The operator reached total depth 21 days ahead of the AFE and $2.07 million under budget. Reducing the dry hole cost more than 30% has positively impacted the development plans for the Carter-Knox field.
The operator and a bit manufacturer cooperatively applied new bit technology to an optimized well program to reduce drilling costs. Attention focused on using recently developed impregnated bits that drill shale at penetration rates equivalent to rollercone bits without loss of performance in the hard abrasive sandstone formations. This technology combined with changes in drilling practices has increased the overall average penetration rate, kept the bit drilling on bottom, and replacing multiple bits. The longer bit runs also reduced the number of bit trips limiting potential problems associated with tripping operations through depleted and sensitive formations.
Enhancements in Design Technology and Performance of Stable PDC Bits Revolutionize Hard Rock Drilling in East Texas Fields; Addendum to SPE/IADC Paper No. 79797
Authors: Fabian Robert T. , Johnson Simon , McDougal Fred 
Published: December 2007

Abstract
This manuscript is submitted as an addendum to SPE/IADC 797971, which discussed emerging successes using a new fixed cutter bit to drill hard rock applications conventionally drilled with roller cone bits. The new bit design using thermostable polycrystalline (TSP) diamond cutters and stability enhancing features has produced results, particularly in the Carthage field in Panola County, which are revolutionizing hard rock drilling in several areas of East Texas. The paper focuses on how teamwork, selective testing programs, and product improvements have combined to create step change improvements in hard-rock drilling capabilities. The paper discusses new information on optimal operating parameters and includes case history examples.