bluuebunny/crossref_metadata_2025_split huggingface dataset:
Magnus: Utilisation of Conductor Sharing Wellhead Technology to Access Additional Hydrocarbons via a Slot-Constrained Platform
Authors: Hicks S. E. , Moore A. , Honey M. , Farmer I. R. , Smart B. , Ekseth R. , Brown D. 
Published: December 2009

Abstract
The Magnus platform, UK Northern North Sea, has been producing since 1983 with all 20 original slots now occupied. Additional infill and ERD production targets were identified and a means of access was required whilst maintaining base field production. Platform modification was selected due to significant commercial advantage over alternative developments. The Magnus jacket was modified to permit running of four additional large conductors into which two smaller casings could respectively be installed.
A tapered jacket profile necessitated preinstalled conductor guide frames to build to 4° inclination at seabed; requiring initial use of the large conductor as a conduit for drilling assemblies. Custom manufactured and specialist equipment was designed and procured to enable successful under-reaming to 54" and installation of 46" conductor. Drilling assembly design and initial pilot-hole profile were deemed critical to subsequent success in running rigid open-ended 46" conductor. Well-critical structural cement was pumped to seabed via world-first use of a 16" inflatable packer and inner string. World-first unguided installation of two 18-5/8" casing strings inside 46" conductor was then achieved. The 18-5/8" casing strings were cemented in place using light cement to preserve (shallow) casing shoe integrity. High resolution multi-shot gyro surveys and a newly developed ‘gamma-wipe’ survey technique were utilised to obtain critical 18-5/8" relative shoe orientation information prior to subsequent kick-off.
Two wells were successfully batch-set to the 13-3/8" casing shoe via one conductor. To mitigate anti-collision risk, safety valve location has been deepened to permit future drilling of all planned trajectories from the new conductor slots (given shallow close approaches).
Modification of existing wellhead technology for close proximity has proved successful. Access to additional Magnus resources via an otherwise full template has been delivered by this Conductor Sharing Wellhead (CSW) technology.
Facilities and Infrastructure Redevelopments and Rejuvenation—A Fast-Track Solution for the Don Area Development
Authors: Matthew Craig 
Published: December 2009

Abstract
The Don Area is located in the Northern North Sea. It comprises the West Don and Don Southwest (Don SW) oil fields, both of which were fallow until 2006. Initial development plans had anticipated a subsea tieback to a nearby host - a relatively slow, costly and potentially complex approach.
Petrofac Energy Developments, who became ‘Operator’ in 2006, conducted an in-depth review of the Don Area, concluding that the refurbishment of an existing Floating Production Facility (FPF) - the Northern Producer - would offer a more cost effective solution by reducing capex and delivering first oil earlier than competing options. Using the FPF would also cut development time, minimize the degree of offshore work required, keep associated costs down, safeguard jobs and radically improve the economic case for the project.
First oil was achieved in April 2009, less than a year after the field development programme (FDP) was formally approved by the UK government's Department for Business Enterprise & Regulatory Reform (BERR).
This paper addresses the key factors that helped decide between competing development concepts. It outlines the field facilities and general approach to the development work along with modifications to the production unit, offtake options and collective benefits. It thereby provides a context in which we can examine the potential for similar development opportunities in the future.
Management, contract strategies and organisational factors played a critical role in the ability of the Operator to deliver this project in record time. In utilising its internal service group expertise, knowledge and resources, the Operator streamlined the project structure and limited reliance on external suppliers. This, in turn, significantly reduced development time and expenditure, optimising oil recovery and returns on investment.
This paper looks at how the application of organisational adaptability, technical knowledge and regional experience helps to achieve a common objective to transform marginal fallow fields into attractive commercial propositions.
Wellbore Instability in Forties: Diagnosis of Root Causes for Improved Drilling Performance
Authors: McIntyre Brett , Dixon Rachel , Mohamed Farid , O'Rourke Tom , Liu Chang , Islam Syed Anzarul , Donald Adam 
Published: December 2009

Abstract
Success in developing and maintaining wells in mature fields is heavily dictated by cost reduction to maintain profitability and maximize production life of the filed. Achieving this relies on better well planning and optimized drilling performances with reduced drilling non productive time. Pertinent to this is the ability to understand mechanisms of wellbore failures, predict and manage operational risks such as wellbore instability, sand production, or hydraulic fracturing. This paper describes how analysis of the historic drilling events have been incorporated to refine mechanical earth models and provides key inputs needed to optimise well plans and adapt drilling practices to changing field conditions. Capturing and classifying historic drilling events is a fundamental key process in understanding the mechanism and causes of well bore failures. A workflow has been engineered to perform such task systematically and efficiently in a field scale multi-well environment. The users are provided with a collaborative common environment to visualize and understand relationships between drilling events in an earth model context. Driven by this new-found understanding, a more accurate prediction of where, when, and how specific problems are likely to manifest themselves can be made. Ultimately it enables closer collaboration between domains and the knowledge gained can be rapidly incorporated into future well planning and drilling operations, while mitigating risks and therefore reducing costs.
Title Pore-Pressure Depletion and Effective Stress Issues in the Gulf of Mexico's Lower Tertiary Play
Authors: Boitnott G.N. , Miller T.W. , Shafer J.L. 
Published: December 2009

Abstract
In this paper we present the results of our study of pore pressure depletion in the Gulf of Mexico's Lower Tertiary Play. Permeability and velocity measurements collected during multiple cycle stress paths are presented. We demonstrate how the data are used for evaluating effective stress coefficient and the calculation of net effective stress for compaction, permeability, and elastic wave velocities.
Rock properties models for the deep water Lower Tertiary sandstones need better calibration for conditions of high initial pore pressures and large pore pressure depletions. Available data indicates that inelastic pore compaction at high drawdowns is possible and significant permeability reduction may occur due to both elastic and inelastic deformations. Velocity changes in response to pore pressure need better calibration in order to improve both characterization and eventual reservoir monitoring activities.
Core measurements used to calibrate logs, interpret seismic data, and constrain reservoir simulations are commonly made at low pore pressures. To mimic reservoir conditions, the tests are performed at reduced external stresses, so as to compensate for the low pore pressures (Pp) used in rock testing. It is common practice to choose a net effective stress that is thought to result in identical rock properties. We show that due to a variety of pore pressure phenomena, the net effective stress for each property is different, and is a direct result of the fact that pore pressure and external stresses act in different ways, causing different stress distributions and deformations within the grains.
Our results lead to the conclusion that the "effective stress" should not be thought of as an equivalent state of stress. Failure to properly apply effective stress concepts can lead to potentially significant errors. For example, laboratory measurements of brine permeability indicate that for these sandstones, the routine core permeability measurements at low pore pressure may underestimate the in-situ rock permeability by 20% to 50% and underestimate permeability reduction due to depletion. Other examples include pore pressure effects that influence interpretation of stress and pore pressure from sonic and seismic data, where the effective stress coefficient has the added complexity of including both rock and fluid components.
Technical & Social Issue of H2S Environment Within Drilling & Operations of Oil & Gas Industry. "Case Study of JOB PPEJ, Sukowati Field - Tuban Block, East Java"
Authors: Syaifudin Suyanto , Oemar Suryadi , Lotong Marthen , Diana Aries 
Published: December 2009

Abstract
In the recent news and publication, many reports have appeared-telling us that some people around Sukowati Drilling Pad exposed by H2S toxic gas and the exposure people got hospitalization. Since 2006 at JOB PPEJ Sukowati field, recorded four incidents in the base line H2S. All of the incidents occur during the drilling activities. JOB PPEJ, BPMigas, and Ditjen Migas spends a lot of energy, time and money in dealing the problem both with community, news paper, and related government.
JOB PPEJ is located in Bojonegoro & Tuban, East Java. The main operation areas concentrated and living in proximity with the community. H2S content in each producing well has a variety 0.6 – 3.8%. Successfully production & exploration within H2S environment started on 1996 at Mudi Field and the year of 2000 starting to explore Sukowati Field.
Hydrogen sulfide presents is a potential hazard. To ensure protection against exposure, JOB PPEJ was applying H2S safety management to protect public health and safety. As part of harmonization, The Local District Disaster Mitigation Task Force Plan (PKDB, Penanggulangan Keadaan darurat & Bahaya) is also initiated into contingency plan. PKDB Team works under Bupati direction to accompany JOB PPEJ operations which is the team consists of Local Government, Army, and Polri, and each of Kepala Desa/Camat.
All of H2S incident at Sukowati Field become big issue written by journalist since the location vicinity to the community area then information access is very easy and fully open. Based on hospitalization data caused by those incidents, only a few persons in the village and or in a house complain or feel and affected by the bad smell, they in illness condition, old, pregnant condition, and suffer from a disease. They hospitalize only in a few days then back home. No one irritant symptom as H2S main effect. If so expose by H2S, the first receiver is JOB PPEJ personnel whom work in drilling rig area.
With unique condition and non technical aspect of H2S environment, now JOB PPEJ with BPMigas and Ditjen Migas were working on it to review, evaluate, and implement both technical and non technical aspect on where drilling rig working on vicinity area. Conveying with this program, socialization to the journalist and Police about Migas activities was being in progressed to solve the current and potential issue refers to previous incident.
Reservoir Characterisation Through Joint Interpretation of CSEM, Seismic and Well Data
Authors: MacGregor Lucy M. , Harris Peter 
Published: December 2009

Abstract
It is well-known that CSEM data are sensitive to the presence of hydrocarbons, but the diffusive energy propagation results in low resolution images. Seismic data are much better suited to resolving structure and some rock properties, notably porosity, but attempts to map fluids from seismic data may be misleading due to the ambiguity between fluid and lithology effects. Careful combination of both types of data based on consistent rock physics helps to overcome their individual weaknesses. In this paper we describe a data integration study on the Luva gas field, resulting in estimates of gas volume and other reservoir properties such as porosity and shaliness.
Reservoir Modeling in Shale-Gas Reservoirs
Authors: Cipolla C. L. , Lolon E. P. , Erdle J. C. , Rubin B. 
Published: December 2009

Abstract
The exploitation of unconventional gas reservoirs has become an ever increasing component of North American gas supply. The economic viability of many unconventional gas developments hinges on effective stimulation of extremely low permeability rock by creating very complex fracture networks that connect huge reservoir surface area to the wellbore. In addition, gas desorption may be a significant component of overall gas recovery in many shale-gas reservoirs. The widespread application of microseismic mapping has significantly improved our understanding of hydraulic fracture growth in unconventional gas reservoirs (primarily shale) and led to better stimulation designs. However, the overall effectiveness of stimulation treatments is difficult to determine from microseismic mapping, as the location of proppant and distribution of conductivity in the fracture network cannot be measured (and are critical parameters that control well performance). Therefore it is important to develop reservoir modeling approaches that properly characterize fluid flow in and the properties of a complex fracture network, tight matrix, and primary hydraulic fracture (if present) to evaluate well performance and understand critical parameters that affect gas recovery.
The paper illustrates the impact of gas desorption on production profile and ultimate gas recovery in shale reservoirs, showing that in some shale-gas reservoirs desorption may be a minor component of gas recovery. In addition, the paper details the impact of changing closure stress distribution in the fracture network on well productivity and gas recovery. In shale-gas reservoirs with lower Young’s modulus rock, stress dependent network fracture conductivity may significantly reduce ultimate gas recovery. The paper includes an example that contrasts the application of numerical reservoir simulation and advanced decline curve analyses to illustrate issues associated with conventional production data analysis techniques when applied to unconventional reservoirs.
Selected examples from the Barnett shale are included that incorporate microseismic fracture mapping and production data to illustrate the application of the production modeling to evaluate well performance in unconventional gas reservoirs. This paper highlights production modeling and analysis techniques that aid in evaluating stimulation and completion strategies in unconventional gas reservoirs.
A Comparative Assessment of 3-3/8-in. Perforators Using ‘Reactive’ and ‘Non-reactive’ Shaped Charges
Authors: Haggerty Dennis , Manning Doug , Leidel David , Barker James , Pettitt Andrew 
Published: December 2009

Abstract
Several recently introduced oilfield perforators incorporate reactive materials that are derivatives of military-based weapons technology. Perforator suppliers claim that using reactive charges facilitates tunnel cleanup creating optimized perforations, thus improving downhole performance leading to increased well productivity. To better understand and quantify differences in penetration and flow performance between reactive shaped charges and conventional shaped charges, a comprehensive test matrix was designed. The performance assessments of reactive versus nonreactive perforators were carried out under controlled conditions in an API Perforation Flow Laboratory (PFL) (API, 2006).
The Phase I tests for this study, which involved shooting into stressed rock under simulated downhole conditions, were conducted in Berea Sandstone targets with mineral-oil flow, to simulate a typical oil-bearing formation. Phase II testing will be conducted in Carbon Tan Sandstone with nitrogen flow, to simulate a typical gas-bearing formation. The Berea Sandstone represented moderate-to-high porosity and permeability rocks with high, unconfined compressive strength (UCS). The Carbon Tan Sandstone will represent low-permeability and medium-porosity rocks with moderate-UCS.
In order to further understand the contribution of the ‘reactive’ component, tests designed for this study are carried out in balanced, underbalanced and overbalanced conditions. Charge performance measurements are taken for both conventional and ‘reactive’ charges in each target reservoir rock. This paper describes the methodology used for the comparative tests between ‘reactive’ and ‘nonreactive’ perforators in the Berea Sandstone portion of the program and summarizes the observations of core penetration, tunnel cleanup and productivity.
Production Data Analysis of Fractured and Horizontal CBM Wells
Authors: Clarkson C. R. , Jordan C. L. , Ilk D. , Blasingame T. A. 
Published: December 2009

Abstract
In recent work, the authors (Clarkson et al 2008a; Clarkson et al 2007; Jordan et al 2006) demonstrated how modern production data analysis (PDA) methods, such as flowing material balance (FMB) and production type-curves, may be adapted to account for the unique reservoir characteristics of coalbed methane (CBM) reservoirs through the appropriate use of material balance and time transforms. Reservoir characteristics related to storage and fluid flow that were addressed included: adsorbed and free-gas storage; single-phase flow of water above desorption pressure (undersaturated coals); 2-phase flow of gas and water below desorption pressure (saturated coals); non-static absolute permeability during depletion; and multi-layer behavior. Example (field) applications of the new PDA methods were limited to vertical wells that were either openhole completed, or slightly stimulated with hydraulic fracturing methods.
In this work, new workflows and analytical approaches are provided for analyzing single- and multi-phase flow of CBM from vertical, hydraulically-fractured wells and horizontal wells. The workflow for single-phase CBM wells, which parallels that used in modern pressure transient analysis (well-testing), includes identification and analysis of flow regimes, followed by (model) type-curve matching and analytical (or numerical) modeling. Pseudotime is modified to account for instantaneous desorption. The analysis and methodology for 2-phase flow reservoirs is more complex, requiring additional modification of the pseudovariables to account for changes in effective permeability. A new workflow is introduced for 2-phase CBM wells that includes the transformation of the well production and flowing pressure data into dimensionless type-curve and flowing material balance coordinates using outputs from the simulator used to history-match the production data. Both simulated and field cases are analyzed to illustrate the new procedures and analytical techniques.
The primary contribution of the current work is the demonstration that modern production analysis methods, modified for CBM reservoir behavior and combined with analytical (or numerical) modeling, can be used to extract quantitative reservoir information from CBM reservoirs which exhibit a wide-range in production characteristics, and completed in a variety of styles. The methods are expected to be used as a pre-cursor to or in parallel with reservoir simulation, to assist with CBM development decisions.
A Probabilistic Approach to CO2 Corrosion Rate Assessment in Gas Pipelines
Authors: Omolegbe Anu , Appah Dulu 
Published: December 2009

Abstract
Extension of field life has resulted in pipelines carrying changing fluids compositions beyond the original designed life. New pipelines are also being constructed in increasingly challenging environment like deep offshore. Therefore, the need arises to ensure the integrity of these pipelines and reduce the uncertainties involved in predicting the future conditions.
The NORSOK CO2 corrosion rate calculation model is used calculate the CO2 corrosion rate in assessing failure of a pipeline. The probabilistic approach to assess pipeline corrosion risks deals with many of the uncertainties common to the data employed and those with regard to the NORSOK predictive model. Rather than consider each input parameter as an average value or &quot;worst case?? value, this approach evaluates the possibility of having 10%, 50% and 90% chances of CO2 corrosion rates obtained from Monte Carlo simulation using Crystal ball&reg;. The corresponding &quot;years of failure?? for the pipeline using a straight line decline extrapolation of the thickness under varying operating conditions were also obtained.This approach reduces the uncertainties involved in predicting future conditions of pipelines based solely on a deterministic &quot;worst case??.
Deepwater Petroleum Exploration and Development in Africa An Appraisal of Factors, Efforts, and Outcomes, 1998-2007
Authors: Iledare Omowumi , Pincomb Richard , Vitrano Derek 
Published: December 2009

Abstract
This paper describes qualitatively the key factors driving deepwater petroleum exploration and development prospectivity worldwide, including but not limited to global petroleum supply and demand fundamentals, availability and accessibility to petroleum resources, technology innovations and infrastructure development, and geopolitics and fiscal arrangements. Quantitative indicators are estimated to analyze these factors with respect to deepwater activity and outcomes in Africa using number of fields discovered, the number of producing and on-stream fields, the estimated average size of discoveries, instantaneous production flow estimates, completion techniques and methods, and capital expenditure compontents and trends. The paper evaluates and compares the attractiveness and prospectivity of the deepwater in Africa using the above empirical indicators by country.