bluuebunny/crossref_metadata_2025_split huggingface dataset:
Creative Combination of New Coiled-Tubing Technologies for Stimulation Treatments
Authors: Boumali A. , Wilson S. , Amine D. M. , Kinslow J. 
Published: December 2007

Abstract
Combining multiple tools or processes can provide creative answers to old problems. An Algerian well was producing from two perforated intervals. The upper zone was previously fractured; the lower zone was underperforming. Stimulation treatment using a hydrofluoric-based acid system was designed for the lower zone to significantly increase the well production. Although there was confidence in the stimulation design, certain operational challenges needed to be addressed. To maximize the economics, the workover operation had to be rigless. The decision was made to use coiled tubing with a newly designed through-tubing inflatable packer to mechanically isolate the zone and deliver the harsh fluids required for the stimulation. The next challenge was setting the packer in a 3-m window between the two zones. If the packer were not correctly positioned the treatment, undeniably, would be misplaced. A wireless casing collar locator (CCL) with pump-through capability was chosen to provide accurate, real-time depth readings prior to setting the inflatable packer in a modular combined tool string.
The designed workover required only a single trip in the well, and the production tubing did not have to be retrieved. With the creation of a real-time correlation log, the inflatable packer was set on depth, and the hydrofluoric-based acid system was pumped into the underperforming zone. Post treatment, the oil production more than tripled. Two technologies were combined in an innovative application that met all operation objectives.
Selecting Ultra-Lightweight Cement for Effective Casing Protection and Hydraulic Isolation: A Case Study
Authors: Fujita K. , Minobe M. , Imazato M. , Johnson C. , Abbas R. , Ucucu A. 
Published: December 2007

Abstract
Lost circulation is a common problem in the massive waterbearing Palaeogene and Cretaceous carbonate formations that extend across all United Arab Emirates fields and the Gulf countries. Traditionally, these formations are drilled with water, 8.10-lbm/gal emulsion mud, or 7.9-lbm/gal aerated mud to minimize losses. Once the 13 3/8-in. surface casing is run, the main objective is to protect it against corrosive brines in carbonate formations and formations at shallower depths. To meet this objective, complete casing-cement coverage all the way to surface must be achieved. Some methods to ensure complete casing cement coverage have been ineffective. These methods included using conventionally extended cement slurries as low as 12.6 lbm/gal, using a stage collar to execute the cementing operation in two stages, and performing remedial, top -down cementing operations after completing the primary cementing operation. Because these methods were ineffective, cemented casings often had major corrosion problems that reduced the life of the wells.
This paper describes the design and results obtained from the first successful use of high-performance, low-weight slurries (HPLWS) and a new ultra-lightweight cement system (ULCS) to cement surface and intermediate casings for Bunduq Oil Co. offshore Abu Dhabi.
An Experimental Approach of the Reversibility of Asphaltene Deposition under Dynamic Flow Conditions
Authors: Shedid S. A. , Abbas E. A. A. 
Published: December 2007

Abstract
Occurrence of asphaltene deposition in producing formation constitutes one of the most serious problems currently encountered in the petroleum industry in many areas of the world. Reversibility of asphaltene deposition represents crucial argument and controversy in laboratory research of the petroleum industry. Deep understanding of this phenomenon is the key for treatment the problem of asphaltene deposition.
The major goals of this study were to investigate (1) asphaltene adsorption rate on carbonate rock surfaces under static condition, and (2) asphaltene deposition and its reversibility under dynamic flow conditions. For the sake of achievement these goals, two groups of experiments were undertaken. The first one measured asphaltene adsorption rate under static condition while the second group was devoted to study reversibility of asphaltene deposition under dynamic flow condition through actual porous medium.
The results of the study indicated that the increase of aging time increases asphaltene adsorption on carbonate rock surfaces under static condition. However, the major part of asphaltene is adsorbed during the early thirty hours of the first contact of oil with rock surface. The results of dynamic flow experiments showed that asphaltene deposition is a continuous process causing permeability damage and is also partially reversible. Furthermore, the asphaltene deposition causes more damage in low permeability rock than that one in higher permeability. The obtained results are expected to have important implications for better formulation of treatments of asphaltene deposition.
Casing Directional Drilling Using a Rotary Steerable System
Authors: Strickler Robert , Mushovic Todd , Warren Tommy , Lesso Bill 
Published: December 2007

Abstract
The hardware used in casing while drilling operations over the past 5 years has proved to be robust and reliable. Several directional wells have been drilled successfully with casing using positive displacement motors (PDMs), but the drilling efficiency was significantly degraded in most of them. This paper documents the drilling of the first two wells to utilize a rotary steerable system (RSS) to improve drilling efficiency when drilling with casing.
Combining an RSS with casing while drilling operations seemed to be a natural way to eliminate the major weaknesses in motor bottomhole assembly (BHA) designs. Rotary steerable systems had not previously been used with casing while drilling because both are new technologies focused on different environments. Casing while drilling developed on land operations while rotary steerables have been popular for offshore projects.
ConocoPhillips has drilled more than 94 wells in the Lobo trend of South Texas since 2001 using the new technique. As part of a technology demonstration project to accelerate the technology to offshore applications, two wells were drilled with an RSS.
The first was an operational test conducted by drilling vertically with the RSS. The second was a full directional test o with a build to 29° directional turn. and then a drop to vertical, including a 100°
How Integrated Well Planning, Technology, and Operations Excellence Impact ExxonMobil's Development Well Results
Authors: Newman Harry E. , Roberts Charles M. , Biegler Mark W. 
Published: December 2007

Abstract
This paper discusses ExxonMobil's approach to designing and drilling world-class development wells. In today's business environment, proper well design and flawless execution are essential as our investments increasingly rely on fewer, more complex, very large volume wells. To achieve success, ExxonMobil has always treated drilling as a core business. This means we value this area of expertise and hire, train, and retain this job skill to contribute to the success of what we do to provide value for our shareholders. We focus on a disciplined approach to drilling and completion investments, full leveraging of our global knowledge, development and deployment of people, technical solutions that balance minimum cost/appropriate risk and full-life-cycle capability, and flawless execution.
Through Bit logging: Applications in Difficult Wells, Offshore North Sea
Authors: Runia John , Boyes John , Lodder Robert Jan 
Published: December 2007

Abstract
Through bit logging is a method for data acquisition using the drill string and bit as a conduit to the well bore.
Two case studies are presented demonstrating the unique capabilities of this technology to obtain data in difficult and troublesome well situations. Both cases were recent (early 2004) wells, offshore North Sea.
Case study 1 concerns an exploration well with a large open salt interval open above the reservoir. Conventional logging tools could not pass the squeezing salt interval, and TBL was used to get past the troublesome interval and successfully obtain quad combo and pressure data. Subsequently, the cement stinger could not pass the same interval, and the TBL bit was again used, this time to cement through.
Case study 2 describes a well drilled into a nearby block, suspected of being depleted. After loosing the BHA, the operator wanted to reduce the risk of getting stuck with an RFT and decided to use TBL to successfully obtain wireline pressure data in the subsequent side track.
Recent developments include a new type of Side Entry Sub System to enable easy surface deployment as well as providing a rapid easy fishing method in case the logging tools were to get stuck during TBL operations.
Compatibility with rotary steering and MWD is under development, delivering the concept of ‘Through Bore Drilling’, the ultimate low cost drilling system. This will allow directional drilling in combination with open hole logging and other operations through the bit, in a single trip.
Conclusion: TBL opens up new low cost/low risk options for data acquisition (and other through bore operations) during well construction. It gives both drilling and petroleum engineers new and low cost options to choose from to optimise well construction and data acquisition. TBL is a first significant step on the way to Through Bore Drilling and has already proven its versatility in a number of ‘difficult well’ cases.
Deepwater Batchset Operations Through the Magnolia Shallow Water Flow Sand
Authors: Eaton Luke F. , Actis Stephen C. , Williamson Roger N. , Vernier Charles G. , Long Jeff 
Published: December 2007

Abstract
ConocoPhillips is developing the Magnolia field with a Tension Leg Platform (TLP) in 4674 ft of water in Garden Banks (GB) block 783 in the Gulf of Mexico. Three wells were drilled at the eventual TLP site to discover and appraise the field prior to sanction of the development plan. Field development plans required drilling an additional six wells at the TLP site where a shallow water flow (SWF) zone is present. The development plan included batch drilling and casing the SWF interval prior to deepening any of the wells to total depth.
The Magnolia batchset program was successfully conducted in 2002 using the Ensco 7500 dynamically positioned semi-submersible drilling vessel. The six well batchset program was drilled at less than the Authority For Expenditure (AFE) cost estimates with zero lost workday cases.
The batch set program included jetting 36 in. casing to 246 ft below mudline (BML), directionally drilling a 26 in. hole to 3264 ft BML while building hole angles up to 17°, and running and cementing 20 in. casing with verified cement returns to the mudline. The SWF sand interval was drilled and cased without "Top Setting" a cemented casing string above the SWF zone. Although individual exploratory wells have been drilled and cased without top setting casing previously, the Magnolia field is the first deepwater field with a SWF zone to be developed in this manner.
Pre-planning for the SWF zone addressed directional drilling issues, water base mud (WBM) design, cement formulation and placement procedures, and logistic supply to the drilling rig. Each well required three 89 ft joints of 36 in. casing, 81 joints of 20 in. casing, 40,730 bbls of blended WBM, and 6,760 ft3 of cement. Five supply vessels were used to provide logistic support for the operation.
This paper will focus on the extensive planning process and the operational aspects of performing a batchset drilling program through a SWF sand in a deepwater environment.
A Conceptual Sensory System for Cross Hole Reservoir Characterization Using a Pair of Horizontal Wells
Authors: Al-Anazi A. , Ershaghi I. 
Published: December 2007

Abstract
This paper presents a new approach for testing and analysis of pressure interference between horizontal wells for mapping heterogeneity of interwell flow systems. The proposed sensor network requires multiple isolated pressure sensors in one of the horizontal wells (the observation well) with synchronized data recording. Using a new derivation, based on integrated and multiple point source formulation, the analytical model to interpret the responses at various nodes of the sensor network has been developed.
The new analytical formulation models the performance of various point source recorders on the observation well based on the Kelvin's point source solution. While the pulsing horizontal well can have its entire completion interval active, each sensor in the observation well is assumed mechanically isolated from the other sensors while receiving transient responses in the immediate domain of its influence. Synchronized responses received at the sensors, are then analyzed to detect preferential trends in transmissivities. Calibrated test with numerical reservoir models have been conducted to validate the synchronized response model.
The proposed approach is an improvement over the previously published interference models between horizontal wells where the active and responding wells are assumed as fixed line sources without being able to take advantage of multiple sensors in the observation well.
The analytical pressure solution, as validated by numerical solution, provides the opportunity to detect flow channels during single phase flow and dynamic fluid-fluid interfaces by time lapse repeat monitoring.
Controlling Cement Operations from an Onshore Operation Center
Authors: Tyberø P. , Allen B. , Helgesen J. T. 
Published: December 2007

Abstract
Driven by industry trends to deliver real-time solutions as well as the high costs to produce hydrocarbons from the mature North Sea fields, a global operator and a global service company have worked together to successfully complete the first fully remote-controlled, offshore cement operation from onshore. By combining proven technology with a specific vision for future operations, this next step in propelling the industry toward the possibility of remote-driven operations was completed on April 27, 2004.
This paper will detail the vision and business cases behind the onshore operation center, remote-controlled cement equipment, and movement of cement operations to the onshore location. It will also present the benefits of controlling cement operations remotely and onshore as it pertains to the working environment in the Norwegian sector of the North Sea. This achievement has proven that remote operation of drilling equipment is a fully feasible and reliable solution, and it has paved the way for further remote operations.
Hibernia Record Well Breaks Extended Reach Drilling and Completion Envelope
Authors: Elsborg Carsten C. , Power Adrian K. , Schuberth Paul C. 
Published: December 2007

Abstract
In 2002 the Hibernia Management and Development Company (HMDC), led by ExxonMobil Canada, embarked upon the development of the northern most compartment of the Hibernia development project, (‘A’ Block). To access these reserves, it was proposed to drill and complete a 31,000 ft measured depth (MD) oil producer with a horizontal departure and vertical depth that would exceed the present day industry extended reach drilling (ERD) envelope.
Successfully drilling this world-class well would require the application and extension of currently available drilling and completion technology. Meeting the project goals would demand the installation of a large monobore completion system with offshore-Canada's deepest downhole telemetry system. The proposed trajectory would require management of weak and unstable intervals across an extended 17,000 ft MD intermediate section. This trajectory would necessitate the installation of record length production casing strings under high friction load. Subsurface tool reliability under extreme cyclic loading would be needed, especially at the lower wellbore sections where downhole tool failures would be costly due to depth and trip time. The project would require the development of effective strategies to mitigate very high circulating pressures and fluid rheology at extended distances. Drill pipe and tool joints would require upgrade to meet the higher anticipated loads for this program. Completion equipment would also require significant enhancements to meet the pressure and axial load requirements of the wellbore. Planned intervention tools would require modification to allow passage through the extended reach sail angle. Wellbore tractors would be refitted and shop testing would be conducted to ensure all tools were ready for application.
To meet these challenges HMDC would leverage existing local experiences1 while at the same time engage recognized international expertise to supplement existing practices. Technical work sessions were conducted during the planning phase to start the communication process to all stakeholders (including service providers) and to identify critical technical boundaries and key technologies to extend the current ERD envelope. The comprehensive review and upgrade of Hibernia ERD practices was effected through external engagement of ERD experts for worldwide lessons learned. Internal resources were accessed to effectively integrate the latest concepts in hole cleaning and wellbore stability. All the while, operational and design revisions were based upon, and complemented by, successful existing Hibernia ERD practices.
Using a Combination of Cement Systems to Defeat Severe Lost-Circulation Zones in U.A.E.
Authors: El-Hassan H. , Abdelrahman M. , Johnson C. , Belmahi A. , Rishmani L. , Jarouj H. 
Published: December 2007

Abstract
The primary objective of cementing an oil or gas well is to provide good zonal isolation between different formations that have been penetrated by the wellbore. Cementing across weak formations with a low fracture gradient usually leads to poor cement coverage, which makes zonal isolation difficult or impossible.
Abu Dhabi Company for Onshore Oil Operations (ADCO) recently had this problem in the water-bearing Palaeogene and Cretaceous carbonate formations that extend across all United Arab Emirates fields and the Gulf region. Several techniques have been used in the past to bring high-quality cement up to surface to protect casing from corrosive brines. These techniques include using multistage tools, pumping conventional lightweight cement to execute the cementing operation, and performing a remedial, top-down cement job after completing the primary cementing operation. Mixed results demonstrated the limitations of these techniques.
Today, with a better understanding of the problem of cementing in these formations, a unique, cost-effective process has been developed to ensure that cement coverage goes up to surface. Essentially, it combines a sequence of three slurry systems, including a novel, ultra-lightweight cement technology, to defeat the severe lost-circulation problem and achieve complete zonal isolation. This paper describes the design and results obtained from the successful application of this new process to cement casings in formation where severe lost-circulation problems are likely to occur.
Unique "Through Tubing" Completions Maximize Production and Flexibility
Authors: Johnson Mark O. , Hyatt Paul G. , Stagg Ted O. , Gantt Lamar L. 
Published: December 2007

Abstract
The challenge with through tubing sidetrack completions has been dealing with small clearances and the lack of ready-made equipment. Over the last 10 years and 450 coiled tubing drilling sidetracks on Alaska's North Slope a number of unique completion designs have been developed to maximize production and achieve vertical/zonal isolation. These completion techniques are now proven, and may make lower cost through tubing sidetracks more feasible for other mature fields.
API Specification 5CT N-80 Grade Casing May Burst or Part Unexpectedly if Supplementary Metallurgical Requirements are not Specified
Authors: Gokhale Samit , Ellis Sean 
Published: December 2007

Abstract
N-80 grade casing is a preferred casing grade for production casing strings. Most often, N-80 casing is ordered to API Specification 5CT without specifying the appropriate supplementary requirements. Casing strings that meet the minimum strength requirements of API Specification 5CT have experienced sudden failures during normal workover and well stimulation operations. This paper presents a case study and lessons learned from the analysis of such a casing failure. The paper is based on the results of metallurgical analyses performed during the investigation.
This paper details the standard manufacturing operations and heat treatment processes performed for N-80 casing ordered to API Specification 5CT, and the result of these operations on the casing's final material properties. By re-heat treating the failed casing with published supplementary requirements in mind, the casing material properties were improved substantially. If the casing initially had the properties of the re-heat treated steel, the failures would likely have been avoided.
Factors that contributed to the N-80 casing failures are presented and the case is made for specifying supplementary tests for verification of fracture toughness.
Implementation of a New Risk Based Well Collision Avoidance Method
Authors: McNair G. A. , Lance S. J. , Codling J. , Watson R. 
Published: December 2007

AbstractA majority of industry operators and service companies have adopted directional drilling collision avoidance rules based on stringent controls to prevent surface collisions and consequent human and environmental damage. These rules are found to be severely restrictive for the optimal positioning of wells through deeper reservoir zones where the level of damage from collision can be contained.A new method is proposed that retains existing rules for avoidance of shallow (severe outcome) collisions and provides the option for use of risk based rules in deeper sections of wells where the outcome of a collision would not be as severe. The risk level of collision with respect to any offset well is calculated and then converted to a Risked Clearance Factor, an established standard for evaluating different levels of collision tolerance in wells.Deep intersections have several characteristics which require separate treatment from shallow intersections. They have high convergence angles which minimize the physical space and distance where a collision may occur and they have lower economic risks of a collision relative to the cost of corrective action.This method has been implemented in a field area of rapid prospect planning and development. The rules are designed to be simple and practical in order to reduce planning and drilling cycle time. A matrix of risk elements, specific to the field area is presented for different depths of collision to help to derive the level of tolerable risk. A case history is presented that shows the clear benefit of utilizing the alternate method.