bluuebunny/crossref_metadata_2025_split huggingface dataset:
Design, Specification, and Construction of a Light, Automated Drilling System (LADS)
Authors: Dunn M. D. , Archey P. J. , Opstad E. A. , Miller M. E. , Otake T. 
Published: December 2007

Abstract
A "typical" North Slope well is a thing of the past. Twenty years ago, a rig would sit on a Prudhoe pad and drill dozens of 10,000 bopd wells. Today, a rig might drill multi-laterals one month, and exploration wells 60 miles from infrastructure the next. Diverse well types and changing economic drivers warranted a new look at North Slope rig designs.
In 1997, BP Alaska began researching what the drilling machine of the future should look like. Conceptual drawings were drafted and several new design tenets emerged. First, the rig had to be safer and more automated. Second, it had to reduce well costs. Third, it had to be lighter and smaller. Fourth, it had to be better suited for cross-tundra rig moves.
In May 2000, BP chose Phoenix Alaska Technology (PAT) to finalize the design, construct, and operate the rig. In March 2001, PAT began constructing a state-of-the-art, fully automated drilling rig that is expected to commence operations on the North Slope in early 2002. The rig weighs less than half that of a conventional North Slope rig of equivalent horsepower. A single operator controls all drilling, tripping, and horizontal setback operations from a computerized control station.
This paper discusses the first four stages of this project: 1) The conceptual design phase by the operator, BP, 2) conceptual design phase by the contractor, PAT, 3) final engineering and specification by PAT and its subcontractors, and 4) rig fabrication. This case study also explores the basis for the design and the features of a light automated drilling system (LADS) that is expected to meet the objectives.
Target Design Based Upon Multidisciplinary Uncertainty Information
Authors: Haarstad Ivar , Lotsberg Oddvar , Torkildsen Torgeir , Munkerud Per Kristian 
Published: December 2007

Abstract
Target design is an important element in planning wells. It is a multidisciplinary and interactive process between geoscientists, reservoir/production engineers and drilling engineers to define the combined uncertainty constraining the size of the target. A methodology and tool for target analysis and quantification of target intersection probability based on drilling and geological input has been developed to promote interdisciplinary communication and help designing realistic drilling targets.
Project Management and Technology Provide Enhanced Performance for Shallow Horizontal Wells
Authors: Sander M. , Norgaard R. , Kern K. , Warren T. M. 
Published: December 2007

Abstract
Seven rigs were employed in the Hay Project to drill eighty-three laterals - 22 triple laterals, 4 dual laterals, and 9 single laterals for oil production, water injection and water source during the 2000/2001 winter drilling season. These laterals were typically longer than 3,300 ft, with laterals as long as 4,060 ft being drilled at a TVD of 1,065 ft. The overall drilling project was completed 21 days ahead of schedule and significantly under budget. Project organization, the application of technology, and agreeable weather conditions were the main factors contributing to this outstanding performance.
Using Predictive Testing to Circumvent Blowout Prevention Equipment Downtime
Authors: Montgomery Michael E. 
Published: December 2007

Abstract
Pulling the blowout preventer (BOP) stack or Lower Marine Riser Package (LMRP) on a floating drilling rig has always cost everyone involved a significant amount of money. However, when operating in the ultra-deepwater theater, those costs regularly exceed $1,000,000 per event. As a result, developing and utilizing methods to ensure operative BOP equipment and systems continues to grow in importance to avoid this downtime cost.
The first known field predictive test on BOPs was conducted on ram locking systems in the North Sea in 1987. Since that time, the tests have been refined to identify other modes of failure so they can be corrected while on the surface, providing increased assurance of their ability to function when they are needed on the wellhead. Additionally, predictive tests have been devised and their effectiveness demonstrated on ram locking systems, connectors, annulars, failsafe valves and control systems.
This paper will outline each of the predictive tests developed and validated from field testing and working with equipment manufacturers, describe the principles upon which they are based, and provide case study examples where they have proven to identify pending failure.
Emulsion-Based Fluid Used to Optimize Casing-Cleaning Operations
Authors: Berg Erik , Nabati-Shoghl Farzad , Saasen Arild , Sedberg Stian 
Published: December 2007

Abstract
The removal of drilling fluids from the cased well prior to installation of critical completion equipment often involves use of special fluids to ensure a complete removal of both the drilling fluid itself and particles attached to the casing wall. This is a critical operation where failure can lead to excessive complications in the subsequent completion operation with stuck packers or formation damage due to particle invasion into the formation as a consequence. Furthermore, these operations have the highest attention from the environmental authorities because casing cleaning operations are considered as highly polluting operations during drilling and completion of a well. Modern drilling fluids used in the North Sea region are designed to meet occupational hygiene requirements and environmental criteria. These drilling fluids are relatively difficult to remove from the casing surface.
The current paper describes in detail a well cleaning fluid system designed to meet these technical objectives with special focus on reducing environmental impact. The casing cleaning fluid system is designed using a partly unstable emulsion, where the surfactants are partly dissolved in the water phase and partly used as emulsifiers. Since the emulsion is unstable, the individual components can be separated after the operation. This allows for re-use and recovery of the fluid components at the same time as the fluids has optimized the well cleaning efficiency. The removed base oil can be used to formulate new drilling fluid or re-used in casing cleaning fluid systems.
The improvement of new designed fluid has been verified in both laboratory tests and North Sea field experiences. Field experience from approximately 30 operations show that the average operation time has been significantly reduced. The paper compares field experience obtained using different casing cleaning operation techniques.
New People, New Rig; Managing Performance
Authors: Blank Bob 
Published: December 2007

Abstract
Long-term business relationships and working teams are difficult to maintain in a cyclical business where activity levels can quickly change. Starting rigs up and building new working relationships is time consuming and can be tedious and unproductive if not properly managed. Both informal and formal processes can be utilized to good advantage in order to maximize safety and productivity. This paper will discuss some of the systems and processes used by one offshore drilling contractor with their customers to focus efforts toward meeting these goals.
Managing the Operator/Supplier Relationship on the Mad Dog Project - The Supplier's Perspective
Authors: Fulks Robert , Cook Allen "Rusty" 
Published: December 2007

Abstract
In mid-2000 BP invited a group of suppliers and drilling contractors to become involved in a deepwater development project in the Gulf of Mexico named "Mad Dog". This project involved building and maintaining unique relationships among the drilling contractors/suppliers, BP and its partners on the Mad Dog field. BP employed a process not used before in the deepwater Gulf known as "Lean Drilling™"1 to foster these critical relationships necessary to the early success of the project.
This paper will detail how BP selected the drilling and completion suppliers during the conceptual stage of the project and how these suppliers were organized and empowered for success. The paper will examine the Lean Drilling process from the supplier's vantage and comment on the effectiveness of this process in terms of technology transfer and other criteria.
Shallow Geohazard Risk Mitigation; A Drilling Contractor's Perspective
Authors: Reed David 
Published: December 2007

Abstract
The introduction of the Offshore Installations (Safety Case) Regulations 1992 and the Offshore Installations and Wells (Design and Construction, etc) Regulations 1996 to offshore operations in the UK North Sea require risks related to the drilling of wells to be kept As Low As Reasonably Practicable (ALARP). The responsibility of the rig owner in this regime is to identify safety critical elements associated with the rig and ensure that these risks are maintained to within ALARP principles. This responsibility also recognises that wellbores attached to the rig may also present a threat to the installation and those onboard. Additionally, the rig owner must take into account well-related safety critical elements.
By using examples, this paper examines why and how a drilling contractor has implemented a Shallow Geohazard Review process in order to mitigate shallow geohazard risks. This paper reviews the operator - geotechnical contractor relationship and identifies where drilling contractor involvement has strengthened the risk analysis process. Finally, this paper summarises the positive outcomes of this process as well as challenges the drilling and geotechnical contractors to bridge the information gap.
Optimizing HTHP Cementing Operations
Authors: Shaughnessy John , Helweg John 
Published: December 2007

Abstract
Successful cementing jobs are critical to economically completing HTHP wells. BP and Schlumberger Dowell have consistently been successful cementing wells at total depths between 22,000′ and 23,000′ and maximum temperatures of 400°F. The proof of successful cement work is demonstrated with record production rates for the state of Louisiana and achieving isolation in sands with over 10,000 psi depletion. The optimization methods and approach will be discussed along with problems experienced and subsequent solutions. Over 15 such wells have been drilled in Louisiana during the last 5 years. This paper will also address the philosophy and procedure of cementing production tieback casing to the surface by reverse circulating.
Evaluation of Deepwater Drilling Prospects Using New Concepts to Identify, Quantify and Mitigate (IQM) Risks for Well Design
Authors: Holasek Fred R. 
Published: December 2007

Abstract
The detailed analysis of a drilling prospect is crucial for a successful well. As the geological events vary dramatically from well to well, the drilling characteristics and risks will also vary. This difference between wells is easily the difference between a successful well and a well fraught with significant safety and financial problems.
An overview has been presented of the steps for the evaluation of a drilling prospect to produce a unique set of drilling characteristics and well design for a proposed well. This evaluation is founded in the fundamental concept of projecting from the known to the unknown.
Wells in the same micro-basin of the proposed well are analyzed in a new way to allow the properties to be projected to the proposed well. This unique analysis allows quantitative comparison of drilling parameters such as shallow flow potential, overburden profile, pore pressure profile, fracture gradient profile, and penetration rate profile. This new concept has it roots based in the fundamentals of micro-basin fluid migration gradients and reservoir seal capacity limits.
Once the analysis of the key wells has been prepared a detailed 2-way time-depth correlation is made from the key wells to the proposed well. Using this detailed correlation along with micro-basin fluid migration gradients and reservoir seal capacity limits, the drilling parameters can be projected to the proposed well bore.
Once this has been done, risks can be identified, quantified and mitigated. A well design and plan can be prepared that has significantly reduced risks. Reducing the risks directly reduces the times that the drilling rig and personnel are exposed to potentially hazardous situations. This means fewer accidents and a safer working environment. As a secondary concern, identifying, quantifying and mitigating risks will significantly reduce the finding costs of hydrocarbon reserves.
Polymer-Free Fluids: A Case History of a Gas Reservoir Development Utilizing a High-Density, Viscous Gravel-Pack Fluid and Biopolymer-Free Reservoir Drilling Fluid
Authors: Campbell S. , Bye G. Kristvik , Morris L. , Knox D. , Svoboda C. , Tresco K. , Hurst G. , Parlar M. 
Published: December 2007

Abstract
This paper presents a case history of the completion procedures applied to a four-well gas reservoir development in the Norwegian sector of the North Sea where open-hole gravel packing was utilized as the sandface completion technique.
The chosen technique to gravel pack the wells was based upon Alternate Path Technology, which incorporates shunt tubes with nozzles on the outside of the gravel pack screen. These shunts create an alternative flow path, allowing slurry to bypass premature bridging and fill any voids beyond the bridge. The use of shunt tubes gives the opportunity of achieving a complete gravel pack without the requirement of a filtercake-sealed wellbore. This introduces the possibility for the filter cake to be removed during the packing operation. As a result, a low-solids drilling fluid that deposits a chemically degradable filter cake can be utilized.
The reservoir pressure in this field required relatively high-density, reservoir drilling and gravel pack fluids (1.65 SG / 13.75 lb/gal). This paper describes the design and development work involved in formulating a mutually compatible, calcium bromide-based reservoir drilling fluid and a Viscoelastic Surfactant (VES) based gravel pack fluid and the subsequent successful application in a subsea field development.
Improve the Economics of Oil and Gas Wells by Reducing the Risk of Cement Failure
Authors: Ravi K. , Bosma M. , Gastebled O. 
Published: December 2007

Abstract
One of the main objectives of a primary cement job is to prevent formation fluids from migrating into the annulus. To achieve this objective, the cement sheath should withstand the stresses induced by the various well operations and maintain integrity during the life of the well. However, the majority of the cement design programs in the industry today consider only the slurry properties and do not assess the effect of the mechanical properties of the cement sheath on the final well design.
A design procedure has been developed to estimate the risk of cement failure as a function of cement sheath and formation characteristics and well loading. A few examples of well loading are pressure testing, well completion operations, hydraulic fracturing, and hydrocarbon production. The design procedure is based on a finite element analysis and simulates the sequence of events from drilling through cement hydration, well completion, and production operations. The cement failure modes simulated are debonding, cracking, and plastic deformation.
The cement is assumed to behave linearly as long as its tensile strength or compressive shear strength are not exceeded. The material modeling adopted for the undamaged cement is a Hookean model bounded by smear cracking in tension and Mohr-Coulomb in the compressive shear. Shrinkage and expansion of the cement are included in the material model.
The need to design a fit-for-purpose cement sheath is accentuated by the sustained casing pressure observed on a number of wells after they were put on production and on some HPHT wells after the displacement fluid was changed over to a well-completion fluid. The pressure in the annulus side sometimes results in an inability to continue further operation. Applications are discussed and examples are provided. From the processes reviewed in this paper, one can estimate the risk of failure of various cement systems and select a fit-for-purpose system that will minimize the overall cost. This process should improve the economics of constructing and producing oil and gas wells (cost effective life cycle design) and also improve safety because zonal isolation failures may be reduced.
A New Approach to Anchoring a Semisubmersible in Deepwater Areas Subject to Tropical Revolving Storms
Authors: Springett CharlesN. , Soles Julian , Zimmerman Evan 
Published: December 2007

Abstract
GlobalSantaFe Corporation has entered into a contract with PPL Shipyard in Singapore to build two new semi-submersible drilling units. The design of these rigs is described in detail in a paper presented in Rio de Janeiro in October 2001 (Ref 1). Santa Fe's objective with these rigs is to satisfy a demand for high capacity drilling units to drill development wells in deep and ultra deep water in the moderate environment areas of the world such as West Africa, Brazil and the Gulf of Mexico. A significant number of Oil Company plans for such locations include a requirement that the unit be capable of attaching itself to a pre-laid mooring system rather than relying on dynamic positioning. This requirement presents a unique challenge to those units that will operate in the Gulf of Mexico. The Gulf of Mexico (and some parts of South East Asia) are subject to Tropical Revolving Storms (hurricanes) which place particular burdens on remote drilling operations.
Historically all rigs in the Gulf of Mexico, with the exception of dynamically positioned drill ships, have been secured and abandoned in the face of hurricanes. It may be that this policy must be rethought in light of the increased number of very large drilling units operating at the outer edges of the continental shelf up to 200 miles from land. Until that happens the policy is still to evacuate which means the mooring system must be adequate to keep the unit on location even if the hurricane passes right over it.
PC-Based System Optimizes and Increases Bit ROP
Authors: Pinckard Mitchell D. , Proehl Tom 
Published: December 2007

Abstract
This case-history paper shows how use of a personal computer (PC)-based sensing, calculation, and display drilling enhancement system (DES) allows drillers to take advantage of years of knowledge accumulated by their predecessors to accurately control weight on bit (WOB) and rate of penetration (ROP) in land-based and offshore drilling operations. Use of the system in more than 100 wells over a 2-year period has resulted in approximately 20% improvement in ROP. Significantly, the drillers achieving this record represented various drilling contractors, cultures, disciplines, and experience levels.
At the heart of the system is statistical process software that analyzes and optimizes WOB and ROP by showing the driller two graphical lines. One line shows what WOB should be (target WOB) and one line shows the actual WOB. The driller manipulates the rig brake to match the actual WOB with the target WOB (a process known as "stitching the line"). Traditional training methods required the driller to learn to "feel" the rig vibrations and sense other signals to attempt to optimize penetration. Gaining the skill to be an efficient driller naturally required a great deal of time and potentially great expense in bit damage and excessive rig time.
A second set of displays available at the rig enables the company man to monitor WOB and ROP from the doghouse. The software samples data often enough to mathematically forecast optimum WOB in real time for any operating condition. A digital recorder system furnishes input to the DES and feeds data to an analytical tool that gives drillers and company men a method of recognizing trends and anticipating coming events. Lessons learned from each job are archived to be used as input to company training.
The paper presents operational details, illustrations, lessons learned, and case histories that show the utility of automated WOB/ROP control and trends analysis as dual means of "managing the challenges of a cyclic industry."
Gas-Influx Events in a Deep Water Exploratory Well: A Field Case History
Authors: Lage Antonio C. V. M. , Silva Paulo R. C. , Gonçalves Clemente J. C. , Borges Francisco A. T. , Mansano Renato B. , Imanishi Roberto M. , Martins Francisco S. B. 
Published: December 2007

Abstract
Several gas-influx events have occurred during drilling ESS-107, an exploratory well in a 1286 m of water depth offshore location in the southeast coast of Brazil, state of Espírito Santo.
The 9 ⅝" casing was set at 3804 m for drilling the final 8 ½" phase of the program. Then, a sequence of gas-influx events affected substantially the overall performance of the drilling activity. The first influx occurrence was observed while drilling at 4719 m and it was initially diagnosed as over-pressured. Consequently, after using the driller's method to remove the gas, the mud weight was increased from 11.3 to 12.5 lbm/gal. After that, some other well control incidents happened in sequence while drilling from 4719 to 4826 m. Despite the suspicion of a fracture breathing formation phenomenon, the mud weight was increased up to 13.7 lbm/gal without putting an end to the flow of gas into the well. In addition, as water based mud (WBM) was routinely flowing through the choke and kill lines mixed with gas, the low temperature of the environment close to the seafloor triggered the formation of hydrate. So, both kill and choke lines were plugged, which was indeed the first occurrence of hydrate formation in deep water while drilling in Brazil.
The present study analyzes the influxes based on all available data, such as daily drilling reports, daily drilling fluid reports, final well report, mud logging data, pressure while drilling (PWD) data, etc, to determine if the fracture breathing formation phenomenon was really the driven mechanism. The control procedures used are also discussed and evaluated. Finally, a proposal is presented to improve the overall drilling performance for the succeeding wells in the area.