bluuebunny/crossref_metadata_2025_split huggingface dataset:
Integrated Flow Modeling Platform Using CAPE-OPEN Standard
Authors: Gainville M. , Roux P. , Pons M. , Pons Michel , Ricordeau A. , Paen D. 
Published: December 2007

Abstract
The design and the operation of petroleum field facilities are facing technical challenges that require numerous and detailed simulations to optimize investments and maximize production. Such calculations rely on a global understanding of production processes that an integrated model from wellbore to topside facilities can supply. To develop such a model, seamless integration of third-party modeling and simulation technologies in a unique software platform is useful and even necessary in many cases.
First, this paper presents the R&D Transient Integrated Networks Analysis (TINA) project that was set up by TOTAL and IFP to address user requirements in term of model coupling, problem solving and data consistency. The TINA's domain of application is design and verification of flowlines from well-bore to topside facilities with a compositional approach. To achieve this objective, the CAPE-OPEN industry standard defined for Computer Aided Process Engineering (CAPE) applications has been used within the INDISS™ platform. The project relies on this platform for integrating modules, on IFP's research knowledge for pipe flow calculations and on third-party software components. TOTAL has brought to the project their knowledge of network design end operational characteristics, as well as the definition of functional requirements of TINA. Validation against field data has also been a profitable input to the project.
Then, this approach is illustrated through several examples integrating three-phase pipe models, valves and surface equipments and also third-party physical and thermodynamic property servers to simulate a deep-water production network.
At last, the paper expresses that the integration of a physical properties calculation server together with advanced pipe models in a software platform dedicated to steady-state and transient simulation enables to simulate deep-water production networks without having to rely on one single simulation solution provider. The interchangeability allows the end-user to choose the most convenient software components for the purpose of a study, and the interoperability allows integrating the latest research improvements together with third-party software components into a global model.
Testing Gas Condensate Wells in Northern Siberia with Multiphase Flowmeters
Authors: Theuveny B. , Zinchenko I. A. , Gazprom Yamburggazdobycha , Shumakov Y. 
Published: December 2007

Abstract
A number of tests were performed in Yamburggasdobycha Gazprom's fields in Northern Siberia area to evaluate the performance of multiphase flowmeters in gas-condensate reservoir applications. The remoteness of the operation and the roughness of winter weather conditions combined with the complexity of the fluid compositions create unique challenges to the successful acquisition of well test data.
The paper discusses the challenges and potential benefits of deployment in line multiphase flowmeters in the difficult operating environment of Northern Siberia.
The reduced logistics and the ability to monitor in real time the true evolution of the gas and condensate wells provide an in-depth view of the actual well performance.
The evolution of the real dynamics of the wells stabilization after a change of choke can be observed and monitored accurately with the in-line Venturi – Dual Energy gamma ray multiphase flowmeter. The importance of the hydrate detection and mitigation processes is essential in the performance of successful tests in the Siberian gas well environment.
The paper details the methodology of the comparison of the well test rates of gas and condensate against traditional means of measurement presently deployed in Siberia. It is based on a rigorous mass balance approach, which enables to consider properly the mass transfer effects when comparing flowrates at different measurements conditions of pressure and temperature.
The presence of hydrates despite the extremely low water content of the effluent is detected by the multiphase flowmeter, which therefore provides also confirmation of the hydrate build up curve.
The challenges to collect representative samples of condensate and gas to ensure proper set-up of the multiphase flowmeter and thus the correct computation of gas and condensate rates are presented, and a number of solutions are described. A discussion of the validity of samples for full reservoir fluid characterization provides insights on the benefits and limitation of sampling in multiphase flow combined with proper conditioning of the samples. The paper further elaborates on the comparison of the fluid composition between traditional surface sampling methods and multiphase testing methods.
The utilization of the dynamic information obtained from the multiphase flowmeter to complement the understanding of the reservoir performance is discussed.
Milling Through an Inoperable Ball Valve at Record Depth Provides for Successful Completion of an Ultradeep Well in the Gulf of Mexico
Authors: Rivas Luis , Powers John L. 
Published: December 2007

Abstract
The Tahiti Field is located in the Green Canyon area of the Gulf of Mexico in water depths in excess of 4000ft. The discovery well was drilled in 2002 in Block 640 and, following appraisal drilling, was subsequently re-entered and successfully tested in 2004. Development of the field followed in 2006 with subsea completions from a drilling vessel but the combination of the water depth, the ultra deep producing zone and the high reservoir pressure presented some major hurdles to the field's exploitation.
Because of the weight of the completion fluid being used (14.8 ppg Zinc Bromide), fluid loss to the formation during completion was a major consideration. To prevent this, a ball-type fluid loss control valve was routinely set in the top frac packer assembly in the production liner, above the producing zone, prior to running the tubing. In January 2007 a well in Green Canyon block 596 was drilled and prepared for completion when the ball valve was damaged which prevented its mechanical actuation process from functioning and put the successful and economic completion of the well in jeopardy. After a review of the alternatives it was decided to perform a milling operation to mill as large a hole as possible through the ball valve and thereby provide access for production. A bottomhole assembly had been designed as a contingency, based on the use of suitable milling technology and a positive displacement motor (a first for this proposed operation), and it was mobilized to the rig, on an urgent basis, along with the required drill pipe work string. The milling job was successfully performed, to drill a 3.800in ID hole through the ball, in a time frame of 2 hours from reaching bottom with the mill, at a considerable savings when compared to other alternatives considered.
In this paper the authors will describe both the completion techniques used and the decision process that resulted in undertaking the milling job. They will go on to describe the procedures and equipment used to achieve its successful completion. Though such a milling job had been performed before, it had never been attempted at anywhere near the record depth of approximately 26,000' and bottomhole pressure in the order of 20,000psi at which the valve was set.
Continuous Improvement in Slop Mud Treatment Technology
Authors: McCosh K. , Kapila M. , Dixit R. , Way P. , Phipps J. S. 
Published: December 2007

Abstract
Oil-based drilling fluids can become contaminated with significant quantities of water as a result of low efficiency well bore displacements to water or brine and from operations such as rig and pit cleaning. The presence of excess emulsifiers and oil-wet solids in typical oil-based drilling fluids allows large quantities of water to be emulsified. These oil-continuous emulsions are often termed slop muds.
This paper presents analytical data on the effects of water contamination on oil-based mud, the resultant slop-mud structure, the influence of shear, and quantification of the critical factors controlling phase-separation and chemical dose. Data will be presented showing the principles of continuous slop-mud treatment both on the laboratory and full-scale defining the important process parameters such as mixing energy, phase recovery rate, recovered drilling fluid properties, and treated water properties.
Development of an understanding of the slop mud stream enabled a novel continuous treatment system to be built which provides efficient and fast phase-separation with recovery of the valuable drilling fluid phase, with significant advantages over current batch-type systems. The process requires in-line injection and mixing of surfactant into the slop mud, then continuous separation of the waste into water and drilling fluid using a gravity separator. The drilling fluid remains as a water-in-oil emulsion containing solids and other chemical additives, which can be reconditioned to acceptable properties for re-use. The water recovery rates are typically 70 to 90 vol% of the total water present in the slop mud. This recovered water is treated using centrifugation, filtration or other water-treatment techniques to meet or exceed discharge consent limits of 15 mg/L total petroleum hydrocarbon. Water collected in the rig deck-drain system which may also be contaminated with oil or oil-based mud can also be treated in the same manner as the recovered slop water.
Because the process allows continuous treatment of the slop mud stream, the resultant equipment has significant benefits over the current batch-type systems including higher throughput and decreased footprint.
Formate Fluids and Environmental Regulations: A Global View of Benefits and Challenges
Authors: Gilbert Y. , Pessala P. , Vaahtera A. , Raivio T. 
Published: December 2007

AbstractThis study compares locational differences in regional and national environmental regulatory approaches to offshore environmental protection in relation to chemicals. Environmental regulations set acceptable discharge limits and define management boundaries for all related actions, from setting strategic HSE policy targets to choosing chemicals for specific operations. The local variations in regulations mean that chemicals acceptable in one location may not pass environmental consent conditions in another. Challenges such variability represents to multinational offshore operators wishing to harmonise chemical risk assessment and identify chemical Best Available Technology (BAT) on a global basis are identified and discussed.Formate fluids are used as an example throughout the discussion. These chemicals are illustrative of some inconsistencies between legal regimes. They demonstrate a low level of toxicity and have positive environmental performance profiles, as illustrated through the use of several case studies. Yet formates cannot be used or discharged in all offshore areas in the same way.Certain regulatory variations can be traced to how ecotoxicological data is utilised within the environmental consent process. Reliance on single test data for setting absolute thresholds may lead to very different consent conditions than combining results from several tests - which together mimic a simple food chain - and applying this as input to risk modelling. For the case study chemicals, the detailed risk assessment approach indicates a positive environmental profile, favourable for discharge consents. In contrast, the single test threshold approach leads to total containment requirements. In the face of such challenges, unified corporate risk assessment criteria can support informed decision making and give operators the benefit of consistent identification of chemicals representing BAT.
Second-Stage Challenge for the PRODML Standard: Adaptive Production Optimization
Authors: Weltevrede Ben , Doniger Alan , Ormerod Laurence , DeVries Stan 
Published: December 2007

Abstract
PRODuction xML (PRODML™) was started jointly by BP, Chevron, ExxonMobil, Shell, and Statoil in early 2005 as a data exchange mechanism to support production optimization within a ‘digital oil field’ context. These companies have been joined by Aspentech, ConocoPhillips, Euriware, Halliburton, InfoSys, Invensys, Kongsberg Intellifield, Matrikon, OSISoft, P2ES, Pioneer, Petroleum Experts, Schlumberger, TietoEnator, and Weatherford. Energistics® has stewardship of PRODML and fosters further development.
There is significant industry interest in implementing digital oil field strategies. Corporate and government initiatives anticipate significant, sustained improvements in recovery and operating efficiencies while maintaining safe operations. This will require robust, trustworthy, implementation of measurement, optimization and automation technologies.
Version 1.0 of the PRODML standard, released in 2006, enables a range of production optimization use cases to handle an information hierarchy which includes time series data. This lays a foundation for adaptive optimization involving interaction between applications and data stores from multiple vendors. Such optimization is important both for situations with low-frequency changes, such as waterfloods, and for those requiring agility, such as compliance with pipeline, liquefied natural gas, and power-generation customer-export schedules that may cycle within a day.
PRODML V1.0 provides a means of transferring data between applications incorporated in simple, common use cases. However, it did not address the task of accommodating changes to the physical configuration of the network, such as the addition of a well or a sensor, without having to manually reconfigure applications. Such changes are commonplace.
In 2007, the PRODML work group focused on managing changes in production network configuration and in the capabilities of system components. The result enables optimization and reporting architectures and data management processes to adapt to changes faster with less effort and fewer errors. PRODML has therefore become a tool which can be used in implementing robust, trustworthy optimization and automation processes.
Several example use-cases are included to illustrate how PRODML can be applied.
New Level of Expandable Connector Qualification Helps Minimize Operational Risk in Solid Expandable Liners
Authors: Ring Lev , Deltombe Philippe , York Patrick , Baker Robert V. 
Published: December 2007

Abstract
Expandable connectors continue to be the Achilles Heal of solid expandables due to the simple nature that the connectors need to sustain their tensile, compressional and sealing integrity, before, during and after expansion. Solid expandable products such as monobore liners and monobore clads, which push expansion ratio requirements to 20% and toward 30%, require connectors with qualification needs that exceed earlier product applications.
The API and ISO qualification bodies are now addressing the need for standardization recommendation procedures for the testing and performance specifications of solid expandable system tubulars and their connecting devices.
Connector failures and inconsistent reporting methods of specifications of solid expandable systems' performance envelops have driven the industry to attempt to apply standard methods of API connector qualification. Even applying conventional testing and qualification methodology for expandable connectors cut on seamless tubulars fell short of thoroughly qualifying these connectors for use in the extreme environment of cold working connected tubulars in situ.
Therefore, a conventional, four-quadrant service load performance envelop has been adapted and developed for the new requirements. Even expansion in "fixed-fixed" conditions has been added to help ensure consistent performance in downhole service. This type of connector qualification has historically rarely been conducted, and then only on a very small range of the possible expansion ratio or for only one size and type of connector.
This paper describes the need, the methodology and the processes required to qualify connectors to this level. This extensive testing and qualification process has yielded connector performance ratings that can be verified with empirical data for every size and style connector for carbon steel as well as CRA tubular materials.
With solid expandable products being used in a wider and broader arena of applications with associated high risk and expensive consequences, it is critical to qualify each size and type of expandable connectors, clearly document these qualifications with both theoretical modeling and empirical data and be prepared to provide the end user with sufficient proof of the expandable connector's performance ratings.
This paper explains how this new methodology provides this level of proof of performance to the end users.
Updating the Geomechanical Model and Calibrating Pore Pressure From 3D Seismic Using Data From the Gnu–1 Well, Dampier Sub-Basin, Australia
Authors: White Adrian , McIntyre Brett , Castillo David , Trotta Julie , Magee Marian , Ward Chris , O'Shea Paul 
Published: December 2007

Abstract
A postmortem analysis of the Gnu–1 well was conducted to help understand the drilling experiences in the context of the pore pressure and stress profiles. The postmortem involved a review of the drilling experiences, the analysis of CAST image data, wireline log data and the LWD logs. This information was used to refine and verify a geomechanical model (in-situ stress, pore pressure and rock mechanical properties) in the vicinity of the Gnu–1 well. Of prime concern was the verification of the pre-drill pore pressure prediction previously undertaken using 3D seismic velocity data and offset well data. Wellbore failure and natural fracture analysis were an integral part of the postmortem. Wellbore breakouts seen in the image data allowed the pore pressure in the 8½" hole section of Gnu–1 to be constrained. Modelling using image data collected in the Athol Formation indicates that the pore pressure does not increase as rapidly as was estimated in the pre-drill study. Pore pressures in the North Rankin Formation and below were consistent with the pre-drill study. The geomechanical model was able to explain the losses seen in the Athol Formation in Gnu–1 when using the mud weights experienced by the open hole at the time of drilling.
Unlocking the Potential of Mature Fields – An Innovative Filtering and Analysis Approach to Identify Sidetracking Candidates in Mature Water Flooded Fields
Authors: von Pattay Patrick W. , Hamer Jeff , Strasser Ralf 
Published: December 2007

Abstract
This paper presents an innovative filtering and analysis approach to identify candidates for sidetracking in mature water flooded fields. It targets bypassed reserves to improve production and ultimate recovery from such fields at once. The method is based on production engineering concepts, it is very time efficient and requires only a minimum of data, which makes it in most cases more suitable than other methods.
The approach provides a filtering concept to select all wells that might have bypassed reserves in their drainage area and provides a step by step analysis to verify, quantify, and locate these bypassed reserves. Further it provides a comprehensive method to develop a production forecast for a potential sidetrack. It also presents a set of criteria to select the most suitable well to sidetrack. Finally it allows leveraging all associated uncertainties by linking the economic analysis to a Monte Carlo simulation, which is critical for a sound management decision.
Whereby, the approach tackles the four most critical factors, how much data are needed, how much resources are required, how long will it take to come to a decision, and what will be the certainty of the output.
Recapitulating, the approach presented here allows selecting candidates for sidetracking in mature water flooded fields based on a minimum of data time efficiently, which allows making the right management decision to unlock some of the potential of these kind of fields at attractive ROI and NPV.
Concise Testing Guidelines for Crosslinked Fluids Saves Time and Money
Authors: Core Jerrod A. 
Published: December 2007

Abstract
Successful fracture treatments that utilize crosslinked fluids are dependent on the fluid maintaining viscosity at down-hole conditions. Pre-job testing of the crosslinked fluids is a critical step in knowing how the fluid will perform during the treatment. Using proper testing guidelines and contingencies in place, the service company can provide operators useable, predictable fracturing fluid test data. Without such guidelines, extraneous testing, unusable data, and job delays can result.
Crosslinked fracturing fluids are tested using a rotational viscometer designed for testing at elevated temperatures and pressures under a constant shear environment. Such viscometers are among the most economical and readily available approximations to the down-hole environment experienced by fracturing fluids. By setting the rotational viscometer to approximated job conditions, and utilizing treatment-specific water and chemicals, it is possible to produce data that predicts the rheological properties a crosslinked fluid will exhibit during fracture treatment.
Before rheological testing begins, the operator and service company must agree upon parameters that are acceptable for the testing procedure. While the ISO-13503-1 document outlines standard practices for measuring the viscous properties of completion fluids, there are job-specific factors that are not addressed in this document. First, the operator may want to specify the exact rheological requirements expected in order to categorize fluid as effective for the treatment. Next, the temperature and shear rate settings must be agreed upon to ensure the viscometer is run at the most probable down-hole conditions for the given job. Finally, the operator or service company may pre-determine the range of chemical additive loadings for several of the crosslinked fluid components (i.e., an optimization path). This paper will outline areas the of a crosslinked fluid test that need to be clearly defined prior to testing, and will show the potential time and financial costs associated with the lack of concise guidelines.
Geochemical Evaluation of Depositional Environment of Parh Limestone, Southern Pab Range, Balochistan, Pakistan
Authors: Naseem Sadaf , Naseem Shahid , Sheikh Shamin Ahmed 
Published: December 2007

ABSTRACT
Geochemical studies of Parh Limestone, through major and trace element analyses, were made to evaluate its depositional environment. Parh Limestone represents Upper Cretaceous period in the Kirthar and Sulaiman provinces of Lower Indus Basin. The Parh Limestone of Turonain-Santonian age is well exposed in NNW-SSE trending Pab Range of Balochistan, which merges into Kirthar Fold Belt northwards. The Indian Plate motion, sea-level fluctuations and volcanism were the main controlling factors responsible for the distribution of elements during the deposition of Parh Limestone. During the cycle of deposition of Parh Limestone the distribution of Mn and terrigenous material (clay) revealed High Stand System at the beginning (Turonian, 91m.y.), which latter turned into Low Stand System and finally terminated as Transgressive System with a very broad shelf environment (Maximum Flooding Surface). The Al/Mn+Fe+Al ratio of the Parh Limestone revealed slow rate of drifting initially and high rate at latter stages due to high rate of sea-floor spreading. The Ca/Mg, Ca/Fe, Mg/Fe ratios suggested hemipelagic environment of deposition. The contents of Ba, Zn and Co were higher than the average abundance in the limestone reflecting partial influence of igneous activity at the time of deposition. The composition of an igneous sill, at the base of Parh Limestone demonstrates ocean-floor tholeiites, affiliated with Mid Oceanic Ridge Basalts (MORB).