bluuebunny/crossref_metadata_2025_split huggingface dataset:
Aconcagua, Camden Hills, and King's Peak Fields, Gulf of Mexico Employ Intelligent Completion Technology in Unique Field Development Scenario
Authors: Jackson Nielsen Victoria B. , Piedras Jose , Stimatz Gregory P. , Webb Tamara R. 
Published: December 2007

Abstract
Economic success of deepwater and ultra-deepwater developments often depends on the use of innovative technologies that can increase production and minimize workover needs to achieve the sought-after field efficiency during the productive life of the field. Intelligent completion technology, a new concept for the oilfield, is one of the technologies that can support these needs. This well completion concept allows the operator to obtain real-time or near-real-time reservoir data, and then, to reconfigure the wellbore production/injection architecture to adapt to the information obtained.
Along with pipeline, platform, and subsea system synergies, three fields in the Gulf of Mexico — Aconcagua, Camden Hills, and King's Peak — are using intelligent completion technology to optimize a marginal reserve base. Located in Mississippi Canyon Blocks 173, 217, 305, 348 and Desoto Canyon Blocks 133 and 177 in 6200- to 7200-ft of water, the production from the three fields will be tied to the Canyon Station host platform, 55 miles from the most distant well location.
Though slight variations exist between the intelligent completion systems being installed in the three fields, the basic design in each consists of:
A production packer with a hydraulic and electric bypass A gauge package for measuring shut-in and flowing pressure from two sand-controlled zones 2 control valves with metal-to-metal seals to control flow from both production intervals A shroud to isolate flow between upper and lower production intervals.
The piston-actuated control valves will be functioned through a direct hydraulic link from the subsea control module. Pressure applied at the subsea control module will allow hydraulic fluid to be directed to the open side of one piston, the open side of the other piston, or the close line, which is common to both valves.
Measuring Formation Anisotropy Using Multifrequency Processing of Transverse Induction Measurements
Authors: Tabarovsky L. A. , Epov M. I. , Rabinovich M. B. 
Published: December 2007

Abstract
Multi-frequency processing of transverse induction measurements (3D Explorer - 3DEX™) allows us to reduce the distortion of interpretation by near-borehole effects. Recently, we have developed a multi-frequency processing technique for determining formation anisotropy in vertical and deviated wells. The method, based on a separation of induction and galvanic modes, provides a fast and stable indicator of anisotropy in real time.
We consider a borehole oriented along the Z-axis. Axes X and Y are positioned in a perpendicular plane. The set of measurements under consideration includes XX, YY, and ZZ data. The magnetic field XX is excited by an X-oriented transmitter and measured by an X-oriented receiver. Similar definitions are true for YY and ZZ components.
We start processing by performing a multi-frequency skin-effect correction on the measured XX, YY, and ZZ data. Correction pre-conditions the data for rotation from the tool coordinate system to the formation coordinate system. As a result of the rotation, we calculate responses XX', YY', and ZZ' where axis Z' is orthogonal to the formation boundaries. Axes X' and Y' belong to the boundary planes. The rotation of multi-frequency processed data does not require knowledge of the full tensor of electromagnetic measurements: the rotation can be done only with the principle components XX, YY, and ZZ.
Rotation isolates the induction mode in the ZZ component and removes the dependence on the vertical conductivity. This allows for applying a very fast processing technique to calculate horizontal resistivity of the formation, Rh. The technique utilizes a modified geometric factor with the transmitter and receiver shifted horizontally with respect to each other.
Next, we produce a synthetic response for XX' and YY' components in an isotropic model with formation resistivity, Rh. The calculated synthetic response is used to correct the field data for the horizontal conductivity. If the formation is isotropic, the corrected signal will be equal to zero. A nonzero residual signal indicates the presence of anisotropy.
The methodology is illustrated with several examples.
Utility and Reliability of Cemented Resistivity Arrays in Monitoring Waterflood of the Mansfield Sandstone, Indiana, USA
Authors: Bryant I. D. , Chen M. -Y. , Raghuraman B. , Raw I. , Delhomme J. -P. , Chouzenoux C. , Pohl D. , Manin Y. , Rioufol E. , Oddie G. , Swager D. , Smith J. 
Published: December 2007

Abstract
In 1999 an oilfield experiment was initiated to test the application of electrical measurement technologies to permanent reservoir monitoring. The principal objective of the experiment was to demonstrate the feasibility of monitoring water movement between an injection and observation well. This paper describes the utility of the data provided by the resistivity arrays and discusses data quality and reliability of the measurements.
Two wells were drilled into the Mansfield sandstone reservoir in Indiana. The D-8 injector well was located in the center of four development wells. The OB-1 monitoring well was offset 233 ft to the southwest in a location midway between the D-8 injector and the No. 3 production well. The injector was instrumented with a 16-electrode resistivity array that was run on the outside of insulated casing and cemented into the annulus of the well. A similar array was cemented into the annulus of the monitoring well.
In March, the D-8 well was perforated and acidized. A surface gauge was used to monitor injection rates and pressures. Initially, injection proceeded at a rate of about 20 B/D, increasing to 100 B/D after fracture stimulation. The D-8 array records responses to perforation, acidization, swabbing, fracturing, and injection. It clearly distinguishes the movement of the waterfront in different zones. The data show good signal-to-noise ratio and high reciprocity. The OB-1 electrical array clearly indicates early water breakthrough via an induced fracture. The arrays show no degradation of signal over the 17-month duration of the experiment.
The experiment has demonstrated the viability of using permanently installed resistivity arrays to monitor movement of oil-water contacts that are some tens of feet away from the wellbore. Results demonstrate the feasibility of using such arrays to monitor oil-water contact movements remote from injection, monitoring, and production wells.
Optimization of Wireline Sample Quality by Real-Time Analysis of Oil-Based Mud Contamination - Examples from North Sea Operations
Authors: Fadnes Finn Hallstein , Irvine-Fortescue Jamie , Williams Stephen , Mullins Oliver C. , Van Dusen Alexandra 
Published: December 2007

Abstract
Oil Based Mud (OBM) systems are often required to be able to drill a well successfully. Their use generally results in a better quality well-bore and reduced drilling time. Unfortunately, this can also result in increased environmental issues as well as difficulties in accurate formation evaluation. One area of formation evaluation that can suffer greatly when OBM is used is wireline fluid sampling. High levels of the miscible OBM filtrate in the final sample render fluid characterisation results questionable and often useless. To obtain high quality oil samples the sampling method and mud system need to be optimized in order to minimize the contamination level.
When an accurate measurement of the level of contamination cannot be made and therefore the amount of miscible filtrate cannot be corrected for, the resulting fluid characterization cannot be trusted. Discrepancies in the current methods of measuring contamination have left many unanswered questions. Furthermore, the resulting reservoir parameters are questionable and must often be discarded.
The ability to measure contamination in real-time while sampling offers an opportunity to revolutionize the sampling method, optimize sample quality, and improve the final results. In addition, this offers the possibility for significant savings in operational time. Analyses of oil samples taken in OBM in the North Sea have shown that it is possible to estimate contamination while sampling using the optical properties of the OBM filtrate and the crude oil. Although these estimates may differ from those obtained through contamination measurements at surface, in several case studies addressed in this paper the downhole contamination estimation proved to be more accurate for a given sample than the corresponding contamination measured at surface. This paper examines oil samples from wells drilled with OBM and discusses the ability to predict downhole contamination from their case histories. The research shows that real-time contamination measurements will lead to improved fluid characterization and consequently improved reservoir engineering.
Decommissioning Offshore Oil and Gas Fields
Authors: Ruivo Fábio M. , Morooka Celso K. 
Published: December 2007

Abstract
Decommissioning offshore oil and gas production systems have been progressively increasing the concern of the industry, government and interest groups through the last years. There are at least two reasons for this sudden regard. First, it is the maturing of several oil and gas fields around the world in recent years. Second, it is the growing impact of environmental concerns in international affairs.
Despite several works published address to some techniques and to potential problems and risks related to decommissioning offshore oil and gas production installations, its procedures are in some extent an innovative issue, especially in the case of deep-water fields such as the Brazilian ones.
Therefore, the motivation of this paper is the novelty of the subject in Brazil, since the national industry is just beginning to deal with the end-of-leasing obligations, which involve decommissioning operations, and the governmental regulatory agency is filling the current gaps in the official guidelines. The main ambition is to stimulate debate about pertinent issues.
A New Generation Multilateral System for the Troll Olje Field - Development and Case History
Authors: Berge Frode , Hepburn Neil , Bowling John , Gronas Tore 
Published: December 2007

Abstract
Norsk Hydro’s Troll Olje field will require about 25 multilateral wells in order to drain the field using the existing sub-sea template structure.
Prior to the development of the Isolated Tie-Back System (ITBS™) described in this paper, three multilateral wells had been installed on the Troll Olje field using System 4503. On these TAML Level 4 wells, junction isolation was achieved with special cement and a resin squeeze. Junction related production problems were experienced on two of the wells with lumps of resin flowing back and plugging surface equipment. One well cleaned up rapidly, whereas the other is currently shut down. The MLT operations on these wells had been completed in 22 days, 17.9 days and 14.6 days, respectively. Although all wells were technically successful and the trend was good there would be a lower limit around 12 days due to all the milling operations required establishing the initial exit and the re-entry to the main bore. In order to further improve the reliability of the junction and the installation time, a new system would be required.
After an evaluation period, the operator (Norsk Hydro) accepted a proposal from Sperry-Sun/ Halliburton to further develop their existing prototype Isolated Tie-Back System for use on Troll Olje. ITBS™ will provide both hydraulic and mechanical isolation, a combined flow area that is larger than that of the tubing above, and an acceptable solution for access to main bore and lateral. The long term objective was to install this TAML Level 5 system in less than six days.
ITBS™ is a multilateral system based on a pre-milled window and on a latch coupling placed in the 9-5/8-in. liner section. After installation of screens in the main bore reservoir section, a whipstock is installed in the latch coupling and the window opened up to drill the lateral. To complete the well, the whipstock is retrieved and replaced by a deflector; and a multilateral junction system is then installed as an integral part of the lateral bore completion. The main component is a flexible hanger with D-shaped legs. This component is attached to the lateral liner on one leg and has a stinger on the other leg. The stinger is oriented and lands in a seal stack in the main bore deflector. On Troll Olje, screens are installed in both the main and lateral bore and the lateral liner is not cemented across the junction. An early prototype of the system was developed in 1998/99. The system was then further developed during 2000 and the first installation conducted for Norsk Hydro in the Troll Olje field in Norway. This paper will discuss the development of the ITBS™ system and also the first installation from a floating rig in the Troll Olje field.
Microbial Enhanced Oil Recovery (MEOR) Technology in Bokor Field, Sarawak
Authors: Ghazali Abd. Karim M. , Hj Salim Mat Ali , Md. Zain Zahidah , Talib Noor Nazri 
Published: December 2007

Abstract
Bokor field was selected as the first field in Malaysia for Microbial Enhanced Oil Recovery (MEOR) technology application which utilizes micro-organisms to facilitate, increase or extend oil production from reservoir through the production of biochemical such as biosurfactant, solvents, gases and weak acids. The field was selected due to its high viscosity crude (4 to 10 cp) and low oil specific gravity of 20° API which could resulted in low recovery factor in major reservoirs ranges from 19% to 25% of its original oil in place. This technology also seems to be attractive for the field as it was initially thought to be potential for for reducing the viscosity of the oil and thus improve oil recovery. In addition, reservoir properties for major reservoirs in Bokor field conform to the basic screening criteria of the MEOR application.
This paper mainly discusses the results of the pilot project on MEOR technology application in Bokor field1. A feasibility study focusing on candidate selection and comprehensive laboratory analysis was conducted to investigate the feasibility of this technology for improving oil production/recovery. Generally, the feasibility study had indicated that there is a potential oil production improvement with no near wellbore impairment. Biodegradation study on the crude sample indicates complete removal of normal/branched alkanes and partial removal of aromatics due to in-reservoir alteration. Laboratory inoculation on the wellhead crude sample indicated that the microbes were able to slightly reduce the viscosity, break the emulsion and increase the solubility of high molecular weight component without damaging the reservoir. In order to prove the laboratory results and further assess the impact to oil production, a pilot test on three (3) selected wells were carried out. A comprehensive monitoring strategy was developed and the performances were monitored for 5 - 6 months.
Over 5 months period, results from the pilot were found to be encouraging. Significant increase in oil production rate and reduction of water cut were observed demonstrating the effectiveness of MEOR application. The average oil production rate for the period increases by 270 b/d which is equivalent to 47% oil incremental.
Microbial EOR Laboratory Studies on the Microorganisms Using Petroleum Hydrocarbon as a Sole Carbon Source
Authors: Han Peihui , Sun Fengrong , Shi Mei 
Published: December 2007

Abstract
Eight kinds of facultative anaerobes using petroleum hydroc-arbon as sole carbon source are screened out from hundreds of oil-bearing waste water samples based on physical and ch-emical condition of Daqing oil field. Systematic biochemical property evaluation and core-flooding experiment show that the eight kinds of facultative anaerobes can grow and repro-duce on crude oil under anerobic condition. They also can de-grade crude oil and decrease its viscosity, produce active substance and reduce the interfacial tension (IFT) between fermented solution and crude oil. Chromatographical analysis shows that the light component of oil which has treated with bacteria increases by 30%, ΣC21-/ΣC22+ increases by 54%.The oil movability got better. Pr /nC17 and Ph/nC18 increases by 55% and 57% respectively. The PH value of the fermented solution reduces from 7 to 5. The acid content in the fermented solution increases from 17.57mg/L to 948.83mg/L. The IFT between fermented solution and crude oil reduces form 35.67mN/m to 8.10mN/m. The viscosity of crude oil decreases from 28.1mPa·s to 18.06mPa·s. The oil recovery by the microbial flooding is about 10%OOIP over that of the water flooding. How the microbes displace the residual oil was directly observed by an electronic microscope during a microscopic core flooding experiment.
Sensitivity Study On Geomechanical Properties To Determine Their Impact On Fracture Dimensions And Gas Production In The Khuff And Pre-Khuff Formations Using A Layered Reservoir System Approach, Ghawar Reservoir, Saudi Arabia
Authors: Zillur Rahim , Al-Qahtani Mohammed Y. 
Published: December 2007

Abstract
A finite-difference hydraulic fracturing simulator has been used to determine fracture growth and geometry in the Khuff and Pre-Khuff formations of the Ghawar gas reservoir. A layered reservoir system approach has been used where each reservoir is divided into several layers based on the geomechanical and flow properties and reservoir lithology. Single and multiple perforated interval scenarios have been studied to compute fracture growth and proppant transport. The effects of geomechanical properties such as in-situ stress, Young's modulus, closure pressure, and rock embedment strength on fracture dimensions have been investigated. Effects of fluid properties such as, injected volume, percentage of pad fluid, leakoff coefficient, etc. have also been investigated.
Several examples with actual field data have been presented in the paper for reservoirs with multiple producing zones in which fracture is initiated in one or many intervals simultaneously so that the impact of perforations, mechanical properties, and flow characteristics could be identified and calculated. These examples illustrate the importance of knowing the formation properties correctly and choosing the most appropriate treatment size and perforation strategy to effectively fracture a reservoir.
A sensitivity study on incremental gas production is also presented in the paper. This study illustrates production increase as functions of reservoir and fracture properties and provides a guideline to optimally choose fracture length and conductivity for an economic and efficient fracture treatment.
Innovative Solution for Cementing Across Very Low Fracture Gradient Formations
Authors: Hun Christian , El-Hassan Hassan , Husam Helou , Hasni A. Latif , Mohsen A. Hameed 
Published: December 2007

Abstract
Lost circulation is a common problem in the massive Simsima and Umm El Radhuma carbonate formations that extend across all United Arab Emirates fields and the Gulf countries. To minimize losses during drilling, 8.10-lbm/gal emulsion mud or aerated mud is often used.
As the result of corrosive brines presence across the formations extending to the shallow depths and causing casing corrosion problems, one of the main objectives of cementing the 9 5/8-in. casing is to ensure well integrity and casing protection by having cement to surface.
In these carbonates, multistage cementing tools have operational problems and frequently develop casing leaks over the life of a well. Top jobs do not guarantee complete linear and radial coverage of the casing along the whole interval. Complete losses are expected with conventional lightweight cement systems, and their set cement properties do not meet requirements for casing corrosion protection. These issues make successful cementing in these formations a real challenge.
To overcome the challenges, a new ultralightweight cement system (ULC) with a density close to that of water and superior set cement properties was used to ensure good casing protection and zonal isolation. This paper addresses the challenge to measure the low density of the slurry and the tools necessary to differentiate between mix fluid and the final slurry.
The new ultra-lightweight cement was evaluated using standard cement evaluation logs, and case studies are presented that confirm successful zonal isolation.
Isolation Of Problematic Zones Using a Cemented Expandable Slotted Liner
Authors: Kent Stephen , van Noort Roger 
Published: December 2007

Abstract
This paper is based on recent job case histories for an operator based in Oman, leading to a case for change.
Operators throughout the Middle East regularly have no option but plan to set casing strings earlier or higher than desired due to problematic geological zones.
Unstable formations can also cause casing runs not to reach depth, resulting in contingency casing strings to be used.
In both of the mentioned scenarios, as a result of being forced to run an additional casing string, the diameter of the well bore through the reservoir could be compromised resulting in a well that is unable to meet production expectations or even reach the planned depths.
The cemented expandable slotted liner is a solution to overcome the issues previously mentioned. For example, if a 9 5/8 in. casing string with an internal diameter of 8.681 in. is set higher than planned due to not being able to get to depth, the cemented expandable cemented slotted liner can be installed below this casing string isolating the problem zone but retaining a through bore of 8.681 in. or larger.
As a result of this technology, operators are able to retain hole size through the next section of the well which could make the difference between the well being commercially viable or not.
In conclusion, there is now a viable alternative to setting contingency casing strings along with a mechanism for operators to consider reducing the number of casing strings that need to be installed to reach target reservoirs. The case histories that will be discussed were completely successful and support the use of the cemented expandable slotted liner in both contingency and planned scenarios.
Development of Improved Performance Roller Cone Bits for Middle Eastern Carbonate Drilling Applications
Authors: Portwood G. , Boktor B. , Bits Smith , Munger R. , Quraini K. , Mutairi B. , Azmi B. 
Published: December 2007

Abstract
Carbonate rock is a predominant Middle Eastern Region geologic feature. Penetration of 16" hole sections through carbonates in the Kuwait Northern Field has in the past required the use of more than one bit. This paper describes an engineering methodology that has produced bit designs that are consistently able to complete the entire 16" Kuwait Northern Field Section with a single bit as demonstrated by production drilling over the course of many bits. Case information is included.
The new design results from a symptom / cause / remedy approach that identifies root causes of unsatisfactory bit life and suggests productive, remedial solutions. Critical drilling information for prior bits was collected and analyzed to identify roller cone bit problems (symptoms). Remedies responsive to each symptom were developed. Remedy engineering was not constrained by traditional design guidelines and certain preferred solutions are considered to be unconventional. Specific, implemented remedies described by the paper include new cutting insert carbide materials and new cutting insert shapes both optimized for Middle Eastern carbonate drilling, and use of seal / bearing systems suitable for extended operation under high WOB.