bluuebunny/crossref_metadata_2025_split huggingface dataset:
An Assessment of Formation Damage: A Case Study for the Cusiana Reservoir, Colombia
Authors: Blosser W. R. , Mujica Santiago 
Published: December 2007

ABSTRACT
The Cusiana reservoir in the Casanare region of Colombia is currently being appraised and developed. Cost effective development of the reservoir will be dependent on applying optimum drilling and completion practices. The purpose of this poster session is to provide a case study history for the approach and evolution of the project as it pertains to attaining an improved understanding of formation damage mechanisms.
Hydraulic Fracturing of High-Permeability Formations to Overcome Damage
Authors: Parker M. A. , Vitthal Sanjay , Rahimi AI , McGowen J. M. , Martch W. E. 
Published: December 2007

ABSTRACT
Gravel pack operations in poorly consolidated, high-permeability formations are often plagued by relatively low production results, which are caused by the constraints of radial flow, damage to the formation and damage to the gravel pack caused by the treatment fluid. Hydraulic fractures will alter the radial flow for improved production results and will reduce the effects of formation damage caused by the treatment fluid.
Data have been generated with several fluid systems that show the damage to the permeability of three different rock types. Fluid loss test results show the expected fluid loss performance of the different fluids. Calculations from recent work are used to show that viscous fluid invasion is also a mechanism for fluid loss control. Fracture conductivity data are provided for 20/40 mesh sands to show performance with the fluids tested. Additional conductivity data with 40/70 mesh sands illustrates the fact that small size gravel pack sands may not provide adequate conductivity for fractured well production. Reservoir simulations compare well performance based on the data provided here.
The Effect of Fracture and Formation Flow Variables on Proppant Pack Cleanup: An In-Depth Study
Authors: Frederick J. M. , Hudson H. G. , Bilden D. M. 
Published: December 2007

ABSTRACT
For many years retained proppant pack conductivity has been used as a major tool in the prediction of optimizing production. As a result, standardized methods of performing proppant pack conductivity tests have been developed and published. The objective of this study was to determine the difference in near wellbore, mid-fracture, and "tip" cleanup of polymer in the proppant pack during fracturing treatment flowback. To ensure optimum formation production, consideration of polymer cleanup between the mid-fracture and the "tip" is necessary to limit the possibility of production limitations due to pressure drop along the fracture length. Cleanup of a proppant pack is influenced by many factors: fluid leak-off, fluid and breaker chemistry, formation mineralogy, fines migration (i.e. crushed proppant and fluid loss additives), temperature, pressure, etc. This study focused on the different cleanup effects determined by the rate and direction of flow in the proppant pack.
The testing methodology used in this study focuses on evaluating the different parameters encountered during actual fracturing treatment flow-back: Removal of filtercake and insolubles due to breaker.Rate of removal of filtercake and insolubles due to flow rate in the fracture.Rate of removal of filtercake and insolubles due to rate of flow through the filtercake into the proppant pack.Rate of removal of filter-cake and insolubles due to interactive flow directions.
Formation Damage of an Unconsolidated Reservoir During Steamflooding
Authors: Hajdo L. E. , Clayton C. A. 
Published: December 2007

Abstract
One of Mobil's principal heavy-oil reservoirs, the Miocene Monarch, in the South Midway-Sunset Field, Kern County, California, is a thick sequence (400 ft.) of unconsolidated deep-sea turbidite gravels, sands, silts, and muds. Disappointing steam injection rates and poor production responses over the anticline prompted a laboratory and simulation investigation of the causes of the shortfalls. High-temperature coreflood experiments were conducted on selected facies, backed by liquid and solids analyses. The experiments showed that fines migration and smectite clay swelling are the primary causes of the restricted injectivity and quantified the severe damage.
Numerical thermal simulators lack the ability to model dynamic formation damage, but it was necessary to capture this progressive loss of permeability to match the field performance. Using a commercial simulator, we represented our laboratory data through the artificial regulation of the temperature dependence of the relative permeabilities. With this, and the recognition of some secondary effects, a very good history match of wellhead rate and pressure responses was achieved. The work shows that the use of standard nitrogen permeabilities gravely over-estimates field performance in this type of reservoir.
Formulation and Field Trial of a Nondamaging, Subhydrostatic Oil-Base Workover Fluid
Authors: Kohli B. S. , Raghunandan _ , Kumawat K. R. 
Published: December 2007

Abstract
The significant formation damage with the use of conventional workover fluids due to filterate invasion of water sensitive zones in the wells having subhydrostatic reservoir pressures can be avoided by the use of nondamaging subhydrostatic workover fluids. New formulations of oil-base workover fluid with minimum specific gravity (0.86) and requisite Theological properties were developed through extensive laboratory studies by using LSHF HSD or a mixture of HSD and stabilised connate crude oil (1:1) and OBM chemicals. The formulations were subjected to field trial in subhydrostatic wells of the Kalol oil field in Western India. The bottomhole studies and / or production performance of the wells worked over with this system, have indicated revival of the wells to their optimum production, which would have been impossible otherwise. The success of the system has found its preferential use for workover operations at all subhydrostatic wells in the Kalol oil field.
The oil-base subhydrostatic fluid system has been introduced for the first time in ONGCL, India. Economically, it is very much viable due to its reusability at different wells. The use of stabilised /treated connate crude oil in equal parts with HSD further reduces the cost of the system with additional benefit of its wax dissolving capacity at perforations.
Polymeric Flocculants Prove Most Effective Chemicals for Wellbore Cleanup Operations
Authors: Holland Brian , Cooksley Timothy , Malbrel C. A. 
Published: December 2007

Abstract
Upcoming zero discharge regulations, high rig time cost, and low oil prices are motivating the industry to look for faster, more effective displacement that reduce the volume of fluid to dispose and decrease circulation time.
A field study conducted in South East Asia showed that more effective displacement can be achieved by adding to the circulating fluid a polymeric flocculant instead of the commonly used surfactants.
A laboratory investigation was undertaken to understand the fundamental mechanism governing well bore clean-up. Its conclusions are as follows: under the highly turbulent flow conditions reigning during displacement operations, saltwater cleans metallic surfaces as well as surfactant solutions;polymeric flocculants form larger and stronger aggregates of solids than surfactants which can withstand better the stresses associated with turbulent flow. This improves the sweeping efficiency of the circulating fluid by increasing fluid drag force on the solids.
A New Development in Gravel Packing
Authors: Nelson Allen C. , Smith Donald M. 
Published: December 2007

ABSTRACT
Gravel packing in wells is made necessary by the need to maintain control of unconsolidated sand formations. The use of gravel packing as a purposeful technique in oil wells has been known at least since the 1930's. Methods of achieving competent gravel packs have varied with time and from place to place. Technical improvements have been made steadily through the years. As with many other processes used in wells, the effectiveness of the developed methods has had to be measured mostly indirectly, by observing results. Direct observation or measurements to monitor the placement or subsequent competency of the gravel pack in detail have not been possible.
An increasing number of fields have been waterflooded in recent years resulting in greater sand control requirements. Higher fluid velocities have made it necessary to gravel pack zones which did not require elaborate sand control measures under primary recovery.
Although operating costs and liner failures have been reduced by gravel packing, a need still exists for improvement. This paper presents completion methods that have been developed and tested wherein rates of 35 B/D/ft. of liner or greater over long formation intervals can be achieved without sand problems. Over 110 wells have been completed using these techniques since June, 1967, with no sand control failures to date.
Critical specifications have been developed involving gravel quality, gravel-sand size ratios, liner slots, hole size, completion fluids, cleanup procedure, cleanup chemicals, and mechanical procedures. Some of these items have been discussed extensively in the literature, others are innovations.
Effects of New Generation Drilling Fluids on Drilling Equipment Elastomers
Authors: Badrak R. P. 
Published: December 2007

ABSTRACT
Environmentally safe drilling fluids have been the subject of considerable interest from governments, operators, oil companies and drilling fluid manufacturers. The use of these drilling fluids has been increasing, this has been especially true for offshore drilling operations.
Drilling fluids can chemically alter the properties of elastomers used in drilling equipment, severely affecting life and function. The products affected include blowout preventers (BOPs), pulsation dampeners, downhole mud motors and drilling bits. This study centers on the effects of selected environmentally safe drilling fluids on BOP and pulsation dampener elastomers.
The properties of these elastomers are presented before and after drilling fluid exposure. The property changes were evaluated with respect to equipment function and performance and exposure time. A wide variation was found in property changes which were dependent upon elastomer and drilling fluid composition.
The performance of elastomers in drilling fluids is strongly dependent upon drilling fluid Chemistry, operating temperature and the type of elastomer chosen for service. Caution and testing were recommended when selecting environmentally safe drilling fluids and compatible elastomers.
A Novel Design Bl-Center Bit Successfully Drills Deep Exploration Well Off the East Coast of Trinidad
Authors: Kalloo C. L. , Attong D. J. , Bickraj Ramsingh , Steele H. E. 
Published: December 2007

ABSTRACT
This paper discusses the application of a novel design two-piece polycrystaline diamond compact (PDC) bi-center bit which was successfully used to drill a deep exploration well, off the East Coast of Trinidad.
New records were achieved on this well by using four different bi-center sizes ranging from 20 inches to 12.25 inches to drill and underream over 10,000 feet of hole. This constitutes the largest and longest section of hole ever drilled with bi-center bits.
Several advantages were realized with the application of this novel design two-piece bi-center bit. The most significant being the elimination of the side loading on the pilot bit. Other advantages include the reduction of drilling torque and the ability to interchange pilot bits.
Gulf of Mexico Mobile Rig Mark Upsurge: How Long Will it Last?
Authors: Plamondon W. N. 
Published: December 2007

ABSTRACT
At the current time, the best offshore rig market in the world is in the U.S. and Mexican Gulf (Bay of Campeche). Will we soon have an oversupply with a continuing return of units from overseas or will there still be a shortage?
The increase in the natural gas prices has driven the U.S. Gulf rig market. Mexico has a great need for additional oil supplies and natural gas. There are currently ten rigs owned by U.S. Contractors drilling in the Bay of Campeche.
For years U.S. oil and gas reserves have been declining. The gas bubble has virtually disappeared. How much activity will it take to reverse the trend and to increase reserves? Most important, will the economic conditions continue to be viable?
A Systems Approach to Downhole Adjustable Stabilizer Design and Application
Authors: Underwood L. D. , Odell A. C. 
Published: December 2007

ABSTRACT
This paper discusses the applications where existing downhole adjustable diameter stabilizers have proven to be beneficial, then identifies additional applications where improved features or capabilities will increase the utility of adjustable stabilizers. Using a systems design approach, those features and capabilities have been incorporated into a new adjustable stabilizer, which is currently under development. Capabilities include a greater range of diameter adjustment, multiple positions, and verifiable twoway communication. The design and construction which makes those improved features possible is discussed. The benefits of those features are demonstrated through computer modeling. Finally, lab and field test results are presented.
A Practical Method To Minimize Stuck Pipe Integrating Surface and MWD Measurements
Authors: Belaskie J. P. , McCann D. P. , Leshikar J. F. 
Published: December 2007

ABSTRACT
A BHA becomes stuck, on average, once for every three wells drilled1. It is very difficult for drilling personnel to monitor sticking during all phases of the drilling operation. There are many situations where monitoring the stickiness of the hole is very difficult. Very often, field crews do not have the time to continuously compute and look at graphs of friction factors, and processing algorithms need to be complimented by automatic warnings. Monitoring sticking while tripping requires knowing the "normal" overpulls, which vary with depth. The authors propose an integrated sticking pipe monitor which automatically calculates friction forces and factors anytime the drillstring is moving, builds normal profiles with depth for comparison and issues alarms to the field crew and driller when sticking is occurring at the BHA.
North Sea Case Histories of Wellbore Stability Predictions for Successful High-Angle Nelson Field Wells
Authors: Ewy R. T. , Ross G. D. , Gast M. R. , Steiger R. P. 
Published: December 2007

ABSTRACT
Eight high-angle (up to 68°) development wells were drilled successfully ahead of schedule and under budget in the Nelson field predrill program. To prevent wellbore instability, which had been experienced on the exploration wells, a new, practical wellbore stability modeling technique was applied. The resulting quantitative guidelines were used to design successful drilling fluid density and casing programs, and well profiles.
Kick and Blowout Control Developments for Deepwater Operations
Authors: Nakagawa E. Y. , Lage A. C. V. M. 
Published: December 2007

ABSTRACT
As the oil industry advances into deep water exploration, the risks of having blowouts increase due to the difficulties related to kick detection and control operation under this condition. New systems, devices and more adequate well control procedures have to be developed to minimize the occurrence of well control problems and blowouts in deep water.
Early kick detection is a key factor for gas influx control. The influx volume has to be minimized for safer well control operations and avoidance of gas in the riser before the BOP is closed.
Well planning also has to be improved. Kick scenarios are being studied with the help of kick simulators for the evaluation and definition of well control procedures. Thus, more realistic kick tolerance margins for the well planning phases, safer well operations and lower costs will be achieved.
Subsea blowout contingency plans are being analyzed for the development of a specific plan. Blowout control methods will be evaluated for specific scenarios. Capping and relief well drilling may be considered as concurrent alternatives to control a subsea blowing well. Topics such as personnel evacuation, oil spill containment, and salvage of the reservoir, rig, and well will also be covered by this plan.
Other aspects to be considered are the development of: (1) a computer system to supervise the BOP to increase its the operational reliability; (2) procedures for minimizing the risks involved during an emergency disconnection in dynamic positioning vessels; (3) a method to eliminate the riser safety margin.
All these studies are being carried out in Procap 2000, a major PETROBRÁS project for deep water exploration and production with the objective of developing full capability to drill and produce in 2000 m of water depth.
Semisub Tender-Assisted Drilling Rigs
Authors: Lorehn O. L. , El Sharkaway A. E. 
Published: December 2007

ABSTRACT
Several major oil companies in the Far East have been having considerable downtime during moving operations with mono-hull tender rigs, particularly during the typhoon season. The use of semi-submersible drilling rigs converted to act as a tender to a platform drilling rig is an excellent replacement for the mono-hull tender and has several significant hidden advantages as well.
This paper compares a mono-hull tender to a semi-submersible in all aspects and describe the modifications that will generally be required for converion. Several significant advantages have been discovered that were not obvious when this solution was first considered. In addition to almost eliminating downtime during erecting, the semi can erect faster, do it safer, and in deeper and rougher water.
Volume Requirements for Directional Air Drilling
Authors: Guo Boyun , Miska S. Z. , Lee Robert 
Published: December 2007

ABSTRACT
It is highly desired to develop a simple and reliable method for determining the air volume requirements for directional air drilling operations. Using Niku-radse's friction factor correlation for turbulent air flow, Angel's empirical model for determination of air volume requirements for vertical well drilling is modified and extended to deviated and horizontal well drilling. The new model is verified by field data taken from air drilling operations. The result given by the this model matches Amoco's experience very well in a wide range of well geometry for vertical wells. A series of charts which are similar to Angel's is presented for quickly determining circulation rates for vertical and directional air drilling operations.
Optimization of Rotary-Shouldered Connection Reliability and Failure Analysis
Authors: Baryshnikov Anatoly , Ligrone Angelo , Ferrara Paolo 
Published: December 2007

IADC and SPE Members

Abstract
This paper presents a case history of drillstring failures in some ultradeep wells drilled in Italy. A new method to optimize the selection of the most suitable Rotary Shouldered Connections (RSC) and failure analysis is developed by using a new factor identified as Fatigue Strength Ratio (FSR). The concept of FSR is mainly based on information available from full scale fatigue tests of RSC's. On the basis of A.8.3 paragraph of API RP 7G this work suggests a wider discussion about RSC's operating limits under combined various static and dynamic loads. A better understanding of static and fatigue characteristics of connections is provided along with plots and equations.

Introduction
Due to the increase in well depths and the complexity of drilling operations to be faced in northern Italy, the control of drillstring element serviceability is becoming more and more important. In fact, apart operating risks, the cost of a complete drillstring can be an important economical factor. RSC's are the weakest items in terms of reliability especially the drill collars' ones; thus the necessity to have a better understanding of their behaviour under applied static and dynamic loads.
Early in the eighties, the discovery of Villafortuna-Trecate field, - north west of Italy, lead to the drilling of ultradeep wells. Operating conditions are extremely severe, since along with the considerable depth of the wells (from 6000 m to 7000 m), high temperatures (up to 180 C) and pressures (over 1000 bar) have to be faced. Furthermore, the drilled formations are very hard and abrasive, while the bottom hole environment is very aggressive due to the presence of H2S and CO2. In such operating conditions an abnormally high occurrence of drillstring failures was recorded. A survey based on the first 7 wells showed that most of the failures took place in the BHA (77%, not including HWDP). A significative number of failures was detected in the drill collars (41% of the total) and the combinations 8" DC with 6 6 / Reg and 9" DC with 7 / Reg gave the highest number of failures (50%), mainly in the last engaged thread of the box (see Fig. 1).
So, in order to decrease the number of drillstring fatigue failures non standard inspection procedures were introduced. Non destructive tests (NDT) of drillstring elements were set at 300 hours of rotation for the BHA, 600 hours for HWDP and the first 20 DP's and 1500 hours for the remaining drillstring. A further survey demonstrated that, after the NDT's procedures' were introduced, the number of failures was actually decreased. However, a high number of cracks -was detected during NDT's (Fig. 2).
P. 935^
Geospatial Modeling Techniques for Understanding Internal Geometries of Complexly Faulted Reservoirs
Authors: Belcher R. C. 
Published: December 2007

ABSTRACT
One of the many challenges in reservoir characterization is the problem of accurately defining, visualizing, and understanding spatial relationships between faults and structural horizons. With the use of new threedimensional geospatial modeling tools geologists, geophysicists, and engineers are able to build geologic models which can be used to verify data interpretations, spatial relationships, and internal geometries of complexly faulted reservoirs.
This paper briefly describes recently developed geospatial modeling technology and the process by which three-dimensional geologic models are constructed. Examples from various studies are presented.
Understanding Borehole Stability: The Power of Computer Animation
Authors: Kwakwa K. A. , Batchelor A. S. , Curtis R. H. , Lanyon G. W. , Batchelor J. W. 
Published: December 2007

ABSTRACT
Well design and planning procedures that integrate mechanical borehole stability analyses can improve overall drilling efficiency and reduce lost time costs substantially. The two key requirements needed to achieve these potential savings are, firstly, effective modelling processes that use all the available information from existing wells and, secondly, communication of the end results in a form that is easily applicable at field level. In this paper we describe both a model and communication method that have been used for several years with considerable success. The end products from such analyses are presented in easily understood graphical and numerical formats developed in response to the requirements of several operators. The computation and presentation are entirely computer-based and are an example of an application that can be incorporated readily into existing computer aided design systems within the industry with the goal of reducing drilling costs significantly.