bluuebunny/crossref_metadata_2025 huggingface dataset:
Continuous Ion Exchange for Wyoming CBM Produced-Water Purification: Proven Experience
Authors: Dennis R. S.
Published: December 2007

Water is pumped from thousands of shallow wells in the Powder River Basin of Wyoming to extract methane contained in coal bed seams, commonly referred to as coal bed methane or CBM. Over 2 barrels of water are pumped to produce a thousand cubic feet (MCF) of gas. The only environmental problem associated with the production of this clean burning domestic fuel is that the water's sodium bicarbonate content is so high that its discharge to the environment is harmful to both plant and animal life.

EMIT Water Discharge Technology LLC and Severn Trent Services, Inc. have teamed together to apply one of STS's technologies for the purification of this produced water. The Higgins Loop Continuous Ion Exchange (CIX) System utilizes cation resins in an efficient mode to remove sodium from the water and concentrate it into a very small brine stream for disposal. The process also reduces the water's bicarbonate content by evolving carbon dioxide gas from the low sodium treated water under slightly acidic pH conditions. Purified water is then neutralized with limestone. This step increases its calcium content and makes the water more suitable for use in irrigation, human consumption, ranching and for aquatic life in rivers and creeks.

The CIX process was first demonstrated in April, 2003 in a well field north of Sheridan, WY. Since then, EMIT has placed 15 more CIX Systems in operation in both Wyoming and Montana treating over 180,000 barrels per day of water. The technology has been accepted by both the gas producers and state regulators as the best available technology (BAT) and most economical process for CBM produced water treatment. This paper describes the reasons for produced water treatment, the purification process and the overall benefits to the industry and environment.
OGP Land Transport Safety Recommended Practice: An Industry Standard for Land Transport Safety
Authors: Tate Derek
Published: December 2007

Driving-related events continue to be the single largest cause of fatalities in the oil and gas industry. Only by implementing a common set of expectations based on industry best practice and experience can the industry as a whole make any significant headway in addressing this issue.

The International Association of Oil and Gas Producers (OGP) formed a Task Force comprised of several leading member organizations with a charter to produce a document that captured established best practices from industry. This document then would be used to provide a benchmark for land transport safety program content. Each member company is expected to implement the document, or Recommended Practice, themselves and to expect implementation by their contractors.

The purpose of this paper is to introduce the Recommended Practice to participants at the 2007 E&P Environmental and Safety Conference, provide insight and background for the document, and to discuss implementation of its elements.
An E-Line Deployed Retrofit Completion With Temporary Automatic Water Shutoff in a Subsea UK North Sea Well Using an Intervention Vessel
Authors: Hartley Michael , Moodie Neil , Rogers Mark , Murphy Bob
Published: December 2007

The Machar field is located in the Eastern Trough area of the UK North Sea. Well 123, a subsea well, was drilled and completed as an oil producer in March 1998 and brought onto production from the Lower Chalk formation in August 1998 upon commission of the production facilities. Water breakthrough was first detected in May of 2001 and despite subsequent intervention to shut it off, the water cut continued to increase until production had dropped off to 3000 BOPD by late 2005. The accompanying 65% water cut presented handling problems at the production facilities that necessitated the well being shut in until additional water handling capacity could be made available.

Additional reserves were present above the Lower Chalk formation in the Upper Palaeocene Sands, but to date they had not been fully evaluated and their potential could well have a significant affect on the future of the field. Therefore, in order to make up for the loss in production, it was decided to re-enter the well and re-complete it so that the Upper Palaeocene sands could be produced. At a subsequent time, when additional production facilities were available, the Lower Chalk could be brought back on stream automatically without further intervention.

In this paper, the authors will review the decision-making process that led to the re-completion, discuss installation planning and execution, and present the results achieved with this unique completion that was installed using an intervention vessel.
Economic Recovery of Gulf of Mexico Shelf Reserves Using an Integrated Approach to Well Services
Authors: Nicosia Chad , Fremin M. E. , Matthews N. J.
Published: December 2007

Economic recovery of shelf reserves in Gulf of Mexico asset has been made more efficient by using a rig-less, through-tubing (RTT) completion equipment package. The package integrates all services and personnel needed for the completion and charges on a day rate-plus-material basis. The RTT approach has been used to repair wells that have developed sand-control issues and still have justifiable reserves to recover. The techniques can be used in abandonment of depleted zones and completing untapped zones.

The equipment package is modular and adaptable to each well's needs, and all personnel concerned have experience in multiple disciplines. The added benefit is a single, simplified invoice; compared to multiple invoices as is the case when using discrete services. The equipment packaging and day rate-plus-materials (DPM) pricing structure allows for a more accurate estimation of cost and reduces unplanned variable costs. There is a lower delivery cost using dual-purpose equipment and multiple-discipline personnel, which has the added benefit of optimizing manpower and equipment needs while decreasing exposure to hazards. Based on the economic drivers of the project, new technology can be implemented, further improving either time savings, increasing reserve recovery, or both. All of the above factors allow for real-time cost-tracking, enabling decision-making based on the current status of the project.

The primary focus of the paper is on remedial completions and workovers to install an economically viable form of sand control for the latter-day producing life of the wells. Case histories demonstrate how the application of this approach has proved to be the preferred method and a viable means to repair sand-control problems for producing zones, complete new zones, and abandon depleted zones for many wells in the Gulf of Mexico Shelf.
A Critical Review of Completion Techniques for High-Rate Gas Wells Offshore Trinidad
Authors: Cooper S. D. , Akong S. , Krieger K. D. , Twynam A. J. , Waters F. , Morrison R. , Hurst G. , Lanclos B. , Parlar M.
Published: December 2007

BP Trinidad and Tobago (bpTT) has been developing highrate gas fields in Trinidad & Tobago since 1999, and has six high rate gas fields currently on production, with several more in planning stages. All of the wells require sand control and this has resulted in five sandface completion types (Open Hole Gravel Pack, Cased Hole Frac Pack, Cased Hole Gravel Pack, Stand Alone Screen and Orientated Perforating). Based on the experience and field performance, open-hole gravel packing has become the preferred option. The techniques used in completing these high rate gas wells as open-hole gravel packs have included both water-packs and shunt-packs. The experiences gained from these operations have now become part of BP's open-hole gravel pack best practices.

The paper details the completion evolution in BP's offshore Trinidad and Tobago high rate gas fields and the relative performance of these completion types from sand control and well productivity standpoints.
Phase Envelopes From Black-Oil Models
Authors: Schindler Miguel H.
Published: December 2007

This paper compares the output of several available empirical black oil model correlations against compositional model results. In this process, the limitations of these models became apparent.

Even acknowledging the imperfections of black model implementation, it is possible to improve the quality of the outputs by means of making the definitions consistent and coherent across the prediction ranges.

A new method is outlined in order to extend the validity of the models in predicting both reservoir and multiphase flow simulations.

This new method is presented here and will be extended in a separated paper.
Repeatedly Increased Efficiency and Success Rate from a New Solids-Cleanout Process Using Coiled Tubing: A Review of Recent Achievements from Over 100 Operations
Authors: Sach M. , Li J.
Published: December 2007

Solids-cleanouts using Coiled Tubing (CT) remain a major part of total activity in the CT industry. Due to the multitude of parameters that influence solids-transport, it can be very challenging to design and successfully execute solids-cleanouts with CT in highly deviated, larger wellbores with e.g. 7″ production tubing, or even larger tubulars installed.

Numerous papers have been written about the development of wiper trip cleanout technology and associated engineering design tools, but this paper is instead focused on important practical issues that directly impact the effective implementation of wiper trip technology in the field. This paper presents the results and lessons learned based on a database, which was compiled from more than 100 solids-cleanout operations using "wiper trip" methodologies. Results will be presented showing how the wiper trip cleanout methodology has improved cleanout efficiency and success rate. Examples are presented showing how the effectiveness of cleanout-bottom hole assemblies (BHA's) involving positive displacement motors (PDMs) and mills has been improved, while simultaneously reducing stress on surface equipment during the operation. Circulation rates higher than specified maximum rates for the PDM are being used without danger of damaging the PDM while reducing the total volume pumped through the PDM during the cleanout by 80-90%. Larger outer diameter (OD) items in the BHA are kept clean of solids while wiper tripping, reducing the risk of stuck CT and protecting sensitive completion components from undesirable interactions with the PDM/mill-BHA. Multiple wiper trips can be performed in one run without the use of drop balls, while having the ability of using selected functions of critical BHA components and full-size drifting of the wellbore for subsequent operations. Field proven procedures are explained, allowing solids-loading in the annulus to be controlled and reduced when necessary, as well as estimates of solids-volumes during the cleanout to be established, based on feedback from the cleanout BHA before any solids have actually reached surface.
From Test Tube to Value Generator: Effective Use of Experimental Design for Uncertainty Analysis and Development Concept Optimisation
Authors: Kloosterman H. J. , Herring T. R. , Tull S. J. , van der Lee J. W.
Published: December 2007

Experimental Design has been used to screen a wide range of potential development options available for an oil rim reservoir, to examine the effect on the development of dependencies between surface and subsurface parameters, and to test the robustness of the optimised project against subsurface uncertainty. The ED algorithm used in this study enabled parameter screening and the parameter interactions to be performed in one step. Development screening was carried out by a process of eliminating options which impacted negatively on recovery and NPV. The interaction between surface and subsurface parameters was assessed and confirmed the robustness of the selected development. Final optimisation of the chosen development was carried out deterministically. Screening of the optimised development against subsurface uncertainty was used to derive a range of production forecasts, to guide the phasing of the development, and to formulate data gathering and appraisal plans.
eDrilling: A System for Real-Time Drilling Simulation, 3D Visualization, and Control
Authors: Rommetveit Rolv , Bjørkevoll Knut S. , Halsey George W. , Fjær Erling , Ødegård Sven Inge , Herbert Mike , Sandve Ove , Larsen Bjarne
Published: December 2007

eDrilling is a new and innovative system for real time drilling simulation, 3D visualization and control from a remote drilling expert centre. The concept uses all available real time drilling data (surface and downhole) in combination with real time modelling to monitor and optimize the drilling process. This information is used to visualize the wellbore in 3D in real time. The system is composed of the following elements, some of which are unique and ground-breaking: An advanced and fast Integrated Drilling Simulator which is capable to model the different drilling sub-processes dynamically, and also the interaction between these sub-processes in real time. The Integrated Drilling Simulator is used for automatic forward-looking during drilling, and can be used for what-if evaluations as well.Automatic quality check and corrections of drilling data; making them suitable for processing by computer models.Real time supervision methodology for the drilling process using time based drilling data as well as drilling models / the integrated drilling simulator.Methodology for diagnosis of the drilling state and conditions. This is obtained from comparing model predictions with measured data.Advisory technology for more optimal drilling.A Virtual Wellbore, with advanced visualization of the downhole process. A new generation visualization system designed to integrate all participants involved, will enable enhanced collaboration of all drilling and well activities in a global environment.Data flow and computer infrastructure.

The combination of the various elements will make e-Drilling very attractive to the new people coming into the industry; the "game boy generation".

e-Drilling has been implemented in an Onshore Drilling Center in Norway. This paper will present the e-Drilling system as well as experiences from its use.
Successful Application of Underbalanced Coiled-Tubing Drilling in Horizontal Short-Radius Re-Entry Well in Hassi Messaoud, Algeria
Authors: Ben Amor Bachir , Ferhat Ali , Qutob Hani , Chopty James , Arnone Maurizio , Schoch Fritz , Barakat Naiem , Khan Rashid , Stulberg Michael , Messas Rafik
Published: December 2007

The Hassi Messaoud field (Figure 1), discovered in 1956, is the largest oil field in Algeria, covering about 2000 Km2 and currently including over 1000 Wells. The field is divided aerially into 25 zones that are separated from each other by low permeability barriers, usually faults. The Cambrian Reservoir is subdivided into four lithological zones designated from base to top as R3, R2, Ra and Ri. The Ra sub reservoir shows the best petrophysical properties with a maximum thickness of 150 m in the western part of the field. The Ra is farther subdivided into five subzones: D1, ID, D2, D3, and D4 based on reservoir properties and depositional conditions.

Well MD-330 was the 4th re-entry well in the Sonatrach campaign. A total of 330 m from landing point were successfully drilled in a continuous underbalanced condition inside D4. As a result, the well productivity was significantly improved, compared with offset wells, due to one of the positive impacts of UBD operations, namely that of the elimination of formation damage.

The combination of Underbalanced and Coiled Tubing Drilling technologies has been proven to be a viable solution to successfully drill horizontal re-entry wells in mature fields where the reservoir pressure is adequate to induce underbalanced conditions using a single phase drilling fluid.

The experience in this field has validated the benefits of the combination of these technologies and has been attributed to the excellent balance between drilling cost and improved productivity. For example, the drilling cost in the short radius re-entry wells drilled with coiled tubing are highly reduced due to the elimination of pipe connection procedures, the increase in rate of penetration, the prevention of conventional drilling problems such as fluid circulation loses and related differential sticking events, the increase in the bit life and reduction in time and drilled distance to reach the production zone.

This paper describes the technical basis for the design and implementation of the Coiled Tubing Underbalanced Drilling project in Hassi Messaoud and highlights the operational key factors and challenges faced during this successful application in Algeria.
Computational Geometry as An Aid to Data Analysis of Drilling Data
Authors: Knudsen Steven D.
Published: December 2007

As the amount of real time data collected during drilling continues to rise, sophisticated methods for analyzing and displaying data are needed to make sense out of large volumes of data. This paper describes a novel use of the concepts of computational geometry to analyze and display data from a downhole drilling data tool.

The use of a mathematical transformation called a convex hull allows one to create a boundary around a set (cloud) of data points. This is most easily visualized in two dimensions as putting a rubber band around the set of points. Imagine that the rubber band is such that it will be tightly stretched when it is around all the points, so that certain points in the data cloud dictate the resulting outline. A convex hull software routine, the best known of which is the"qhull" program from the University of Minnesota, fits line segments around a cloud of points in up to nine dimensions. Utilizing the convex hull output one can calculate the volume in 3-D or area in 2-D described by data clouds. The result is used as an indicator of bit and drill string behavior.
Applying Downhole Real-Time Data and Composite IPR Technology To Optimize Production of Multiple-Zone Intelligent Wells
Authors: Konopczynski Michael , Ajayi Arashi
Published: December 2007

The application of intelligent well technology has greatly increased, however, integrating real-time data into a reservoir management work flow, and accurately predicting the hydrocarbon delivery to meet optimization requirement is still an elusive task. This paper presents a single intelligent well optimization strategy and composite IPR technology to fill this gap. By referencing individual zone production to one nodal reference point, a general model was developed to combine the fluid flow from individual zones. The model integrates each individual zone's IPR with the production constraint equipment's flow performance to generate composite IPR's corresponding to the relative ICV choke setting. By integrating this composite-IPR with tubing flow performance, the hydrocarbon deliverability of the intelligent well and production fluid allocation of each zone can be reasonably predicted. Furthermore, to convert the real-time monitoring data into tangible value, this paper has proposed a two intelligent well optimization strategies. By combining the gauge data with a real-time flow distribution model, the production allocations of individual zones can be predicted. The composite IPRs provide operators reliable data to accurately predict the hydrocarbon delivery of the well and enable them to make decisions to meet optimization requirements.

Assuming a hypothetical two-zone intelligent well case, a computer model was developed to demonstrate this composite IPR method. This work provides engineers with a reliable tool for designing, analyzing and optimizing the production and downhole ICV operations of the multiple zone intelligent production well.
Learning To Trust Your Data: Real-Time Quality Integration for G&G Professionals
Authors: Gregory P. W. , Schneider S.
Published: December 2007

Software advances in recent years have changed the way Exploration & Production (E & P) companies utilize and manage geotechnical data. Contemporary geoscience interpretation applications are "data hungry" and able to consume more types of data from diverse sources at a higher rate of speed. Because of the variability of data, technology, data capture methods and data accuracy levels collected over the extensive operating history of a Well's life cycle, the challenge in the E & P industry remains how can you trust the data that you depend upon daily? The more important question might be "how can you NOT trust the data" upon which multi-million dollar drilling decisions are being made on a regular basis? This paper describes how the application of contemporary software technology can improve the decision-making process by adding a dimension of confidence through data quality as data is moved between various geoscience applications and corporate databases.
Right Bit, Right Application, Right Time: Case Studies of Enhanced Bit Design Process
Authors: Yoosuf Sajad , Goebel Tom
Published: December 2007

Properly matching drill bit design to target formation in order to achieve desired performance has always been a challenge. Due to the recent steep rise in drilling activity, the time available to plan, evaluate, conceptualize, design and test bit designs has been cut short drastically.

This paper describes application-specific design solutions that enable rapid optimization of detailed aspects of drill bit design. Specifically, the focus is on a method of customizing or "matching" drill-bit-to-specific-application based on operator requirements, formation to be drilled, drilling parameters and rig capabilities.

In hard-to-drill Mid Continent applications, this simple but engineered and proven process expedited selection of the right bit at the right time for the right application. Eliminating unnecessary lines of communication and moving bit design closer to the customer interface – or to the rig itself -- the process streamlined product development and manufacturing by incorporating "first-hand" customer input into the bit design function.

Central to the process are a number of advanced design tools that enable application-specific design solutions to optimize detailed aspects of the bit design, such as precise cutter arrangement and placement, as well as force-, volume-and energy-balancing.

As summarized in three case histories, application of this bit design/selection process significantly improved customization of optimum bit designs for the US Mid Continent, where increasing target depths and more complex well profiles in hard-to-drill formations rendered use of "generic" tools less than optimal.
Well Management Under Uncertain Gas/ or Water/Oil Ratios
Authors: Bieker H. P. , Slupphaug O. , Johansen T. A.
Published: December 2007

In the daily operation of an oil production system, it is often required to choke back some of the oil production wells to ensure that the processing capacity is not over-utilized. When the capacity of some processing resource is over-utilized, wells having large ratios between the consumption of the resource and the oil production rate are choked back. When there is free processing capacity, the chokes of the wells having small ratios are opened. Often, the gas or water oil ratios (derived from the water cuts) are used as such ratios. These ratios are uncertain. This paper proposes to use information about the uncertainties of the gas or water oil ratios to find the order of opening and closing the wells to maximize the expected total oil production rate from the wells. In a computational study based on field data, it is found that the order may be different from the one found using the expected value of the gas or water oil ratios and that the expected total oil production rate was increased by 10.1 % for this particular case.
Uncertainty Assessment on Well-Performance Prediction for an Oil Producer Equipped With Selected Completions
Authors: Ouyang Liang-Biao
Published: December 2007

In order to make an appropriate business decision on well completion, the impacts of uncertainty of key completion parameters on well performance must be carefully evaluated to reasonably estimate the well performance. A procedure has been proposed for the evaluation purpose. The procedure will be applied to five common types of well completions to illustrate the importance of the proposed uncertainty analysis.

A field case study will be discussed in detail in the paper to demonstrate the uncertainty assessment process for efficient completion designs. The case study will be focused on a horizontal oil producer where different completion options have been proposed. The relative impacts of different parameters on the well production will be investigated to identify the major parameters that could affect the well production the most. The field case study will help us to understand the importance of the uncertainty analysis and its potential impacts on the final completion selection.
Natural Gas Dehydration: The Suitability of Solid Desiccant Technology in Nigeria
Authors: Odunowo Tioluwanimi
Published: December 2007

The dehydration of natural gas cannot be neglected in processing the gas to consumer specifications. Glycol dehydration (the conventional dehydration method used in Nigeria) has its associated problem – the venting of pollutants such as Methane, VOCs (Volatile Organic Compounds) and HAPs (Hazardous Air Pollutants). This constitutes an environmental hazard and also loss of valuable gas that could be sold to generate revenue.

This problem need not continue, as improved solid desiccant technology has proven to be capable of solving it. This paper presents this view in a systematic analytical approach. To validate this view, environmental and economic analyses were carried out and the results obtained demonstrate that desiccant dehydrators are preferred in terms of cost savings and environmental friendliness. Thus they are viable alternatives to the conventional glycol dehydrators.
Challenges in Working Over-Severely Corroded Water Injectors for PWRI Application
Authors: Kumar Manish , Chin HonVoon , Malcolm Alex
Published: December 2007

The Nelson field is located 120kms offshore from Aberdeen in the Central North Sea. It is an important asset for Shell UK in the North Sea. This paper highlights the important steps that Shell UK is taking towards reducing its oil to sea discharge and meet compliance with OSPAR regulations. The heavily corroded state of the Nelson water injectors posed a major challenge towards successfully recovering the slot and executing a workover, which would allow produced water to be re-injected into the reservoir instead of being discharged to the sea.

This paper details the work scope, the plans and execution of the workover. It highlights the challenges that were faced by the team to deliver a well capable of produced water and seawater injection. The paper details the final results obtained from the successful campaign on the Nelson platform.
Enhanced Solids Removal Techniques From Ultra Low Pressure Wells Using Concentric Coiled Tubing Vacuum Technology
Authors: Rafferty Phil , Ennis Jim , Skufca Jason , Craig Steven
Published: December 2007

The removal of solids from the Tyonek field gas wells has proven to be a major challenge for the operator.

The field has an exceptionally low bottom hole pressure gradient of ~0.1 psi/ft. This means that traditional two phase sand removal operations using coiled tubing had not been successful. Even following the development of engineered cleanouts, the bottom hole pressure was just too low to support economic returns.

The option of reverse circulating would also not be feasible due to the massive quantities of nitrogen required to succeed.

Following reviews, the most efficient method of cleanout was identified as using a Concentric Coiled Tubing Vacuum Technology (CCTVT) system. The CCTVT essentially provides a second annular return route for wellbore solids while simultaneously boosting the return pressure. This permits the cleanout to be performed with fluid only, a significant logistical and financial saving over two phase operations.

This paper will describe the system technology, engineering planning, well control considerations, system limitations and the observed operational and production results of a five well campaign from the first CCTVT operations conducted in Alaska as well as the first application on an offshore platform.
Dewpoint Pressure Estimation of Gas Condensate Reservoirs, Using Artificial Neural Network (ANN)
Authors: Akbari Meisam Karbalaee , Farahani Farhang Jalali , Abdy Yaser
Published: December 2007

Dew point pressure is a crucial parameter for evaluation of gas condensate reservoirs. Hence, the availability and accuracy of this property has been the main bottleneck for the reservoir simulation and development.

Although the dew point pressure can be determined experimentally from collected laboratory samples frequently these measurements are not available. In these cases, fluid reservoir properties are determined with the use of empirical correlations (explicit methods) or they can be determined iteratively using an equation of state (EOS).

Theoretical results and practical experience indicate that feed forward network can approximate a wide class of function relationships very well. This property is exploited in modeling petroleum engineering process.

In this work, a set of conventional feed forward multilayer neural network have been proposed to predict dew point pressure of gas condensate reservoirs. The accuracy of the method is evaluated by its application for dew point pressure estimation of various reservoir fluids not used in the development of the model. Furthermore, the performance of the model is compared against the performance of other alternatives correlations reported as the most accurate and general correlations for dew point pressure prediction. Results of this comparison show that the proposed method out performs the other alternatives, both in accuracy and generality.

The network was developed using experimentally Constant Volume Depletion (CVD) measured condensate sample of south pars reservoir and collected data from literature of 111 gas condensate samples covering a wide rang of gas properties and reservoir temperature.

The network has an average absolute error of 2.573%, 3.832% and 2.612% for training, validation and test processes, respectively.
Advanced Collaboration Environments in Practice in BP's Gulf of Mexico Operations
Authors: Castro Albino , Schnellhardt Jeff
Published: December 2007

While central control rooms have been in use for industrial plants, pipelines, and drilling operations for many years, the BP Gulf of Mexico Production Advanced Collaborative Environment (GoMP ACE) is the first live environment to support production and startup operations across multiple assets. The ACE tackles the traditional onshore/offshore team culture and transforms it into a new virtual team that is not restricted by miles and bodies of water. The ACE implementations will increase BP operations efficiency and integrity management through enhanced onshore/offshore collaboration, cross-asset collaboration, faster response to critical situations, and proactive interventions. It is part of BP's FIELD OF THE FUTURE program in Gulf of Mexico (GoM), hosting and enabling most of the program's applications (1,4,) A number of ACE installations are taking place across BP globally, presenting valuable opportunities for shared learning in implementation and usage (5).

To achieve these benefits, a 50,000 square foot facility was designed to host collaboration areas within the permanent workspaces of more than 200 production operations support staff across various disciplines. The extensive technology inventory available to support the ACE includes a secure digital network that links the offshore platforms with eight onshore control rooms, 40 video-conference cameras, and an innovative matrixed display capability that routes real-time visualization of offshore data on any of the 200 plasma, LCD, or projection screens. In order to facilitate the two way conversations between the onshore and offshore teams, upgrades were also made to the collaboration facilities offshore.

The BP GoM ACE is not just about technology and workspaces – these are key enablers that drive processes and behaviors that enable a new organizational culture. A focused training and enrollment program was executed to accelerate learnings from other projects, build organizational alignment, and drive new multi asset behaviors. Communities of Interest and a recurring Pulse Check process with the resident teams have also been implemented to ensure that the model continues to evolve and adapt based on learnings over time or changing needs of the organization.

BP GoMP ACE Benefits include: Reduced offshore people-on-board (POB) and fewer or eliminated trips offshore for a subset of activitiesCulture evolution of field and office towards one virtual onshore/offshore asset team, with access to extended network of other assets and central engineering authoritiesReduced cycle times and better decisions faster from improved real-time data context and access to key resourcesStandardized platform across assets to drive business unit consistency and implement additional FIELD OF THE FUTURE capabilityFocus on continuous improvement to apply feedback and learnings towards enhancements and new capabilities
Abrasive Perforating via Coiled Tubing Revisited
Authors: Schultz Darcy , Thompson Dave , Whitney Dwayne
Published: December 2007

In certain formations in the Western Canadian Sedimentary Basin tortuosity resulting from conventional perforating gives rise to high near well bore friction pressures during hydraulic fracturing operations and the resultant increased likelihood of premature screen out.

This paper will discuss the benefits of Abrasive Perforating via coiled tubing and present a number of case studies including vertical and horizontal wells. A number of previously published papers and laboratory investigation has suggested that significant benefits may arise from abrasive perforating; actual well data will be used to test these hypotheses. This paper will present empirical data showing reductions in near well bore friction of up to 92%. Furthermore, benefits of Abrasive Perforating via coiled tubing and overcoming the operational challenges will be discussed.
Coiled-Tubing-Deployed Fracturing Service Yields Increase in Completion Efficiency
Authors: Peak Zeke T. , Janik Kyle Z. , Marshall Eric J. , Wilbanks Brian A.
Published: December 2007

The recent increase in oil and gas prices has fueled the demand for operators to decrease completion times without jeopardizing production seen with current conventional completion methods. A recent application of coiled tubing deployed fracturing service (CTDFS) not only displayed an improved efficiency in completion time but created one of the most prolific wells in the Willow Springs field for ConocoPhillips. A total of 18 individually designed, hydraulically fractured stages in the Cotton Valley and Travis Peak formations were completed in 73 hr of continuous operations, including a round trip of tubing to switch methods of isolation. The increase in completion efficiency is largely contributed to hydra-jetting perforations in the casing and then immediately hydraulically stimulating the formation by way of the annulus.

This paper will present the process by which the CTDFS was executed and the observed results.
A Successful Dual-Casing Exit Campaign
Authors: Cruickshank Brian , Grigor Charlie , Parker Lewis , Pape Gary
Published: December 2007

Successful Dual Casing Exits are becoming more commonplace in today's oil field. However, there are still many challenges involved with this type of work. This paper will outline the successful completion of a two well campaign carried out in the Arabian Gulf along with the problems encountered, lessons learned, the post job conclusions and the recommended way forward for future jobs.

The task for this campaign was to design, build and supply a system that would be able to set inside 4 ½″ casing and successfully mill a window out of this smaller pipe into the surrounding cement then mill out through the larger 9 5/8″ casing. Having milled the window through both sizes of casing, a rat hole would have to be drilled deep enough to suit the subsequent drill ahead BHA. Although these window milling BHA's were to be conveyed using pipe, like traditional TTRD exits, this campaign would utilize PDM motors to provide the rotation for sidetracking the wells.

On both occasions, the sidetracks were completed and the customer was able to continue the drill ahead operations as planned. There were many lessons learned throughout the campaign. From the initial design stages, through the manufacturing phase and finally onto the operational issues, the lessons learned were significant and will be used in the future advancement for this type of work.

This technical paper will show the importance of this campaign which, with the lessons learned, will lead to many more successful dual casing exits being carried out.
Rigless Tubing Repair Using Permanent and Retrievable Patches at Prudhoe Bay, Alaska—Continued Analysis and Current Applications
Authors: Julian J. Y. , Cismoski D. A. , Sack J. K.
Published: December 2007

At Prudhoe Bay, Alaska, non-rig tubing repairs have become a viable alternative to rig workovers (RWO's). They provide an economic remediation for wells with production tubing by "A" annulus communication. Electricline (EL)-set patches can eliminate tubing communication at a significant cost savings. They are particularly attractive in areas where RWO cost is significant, such as offshore, remote, or arctic locations. The advantage of tubing patch repair over a conventional RWO is that there is no need to pull tubing, resulting in the well being returned to service faster. Typical patch deployment costs are less than 5% of the costs for tubing replacement with a RWO. To date, 263 permanent and retrievable tubing patches have been set in 181 wells at Prudhoe Bay.

This paper discusses the history of conventional tubing patches at Prudhoe Bay and recommended pre-patch diagnostics. The paper also provides a systematic approach for the design and deployment of conventional tubing patches.
Feasibility Study of Ultrasound for Oilwell Stimulation Based on Wave Properties Considerations
Authors: Caicedo Sergio
Published: December 2007

Ultrasound or high frequency (20 kHz-100kHz) pressure wave has been used in diagnose and treatments in different areas, such as: medicine, dentistry, civil engineering, and many other industrial applications. In Oil industry there are applications such as pipeline inspections, fluid velocity measurements, etc, but to the present its application in formation stimulation has been incipient, and only few lab and field test experiences have been reported. Stimulation with ultrasound is not a common operation offered by oil service companies. In order to visualize the real potential of ultrasound in oil well stimulation, it is necessary to understand the wave phenomenon, its properties, the parameters that define its behavior, and its interaction with the propagation media. This basic knowledge together with the understanding of the different formation damage mechanisms are the keys to comprehend the real potential and application window of the ultrasound in oil well stimulation. The present paper presents the theoretical basis of ultrasound and wave phenomena that must be considered when thinking about stimulation with ultrasound. Finally some suggestions about the application window of this technology are given.
Novel Coiled-Tubing Spoolable Connector Deployment in the Norwegian Sector of the North Sea
Authors: Bolarinwa S. O. , Mckee M. , Espinosa F. F. , Cochran J. , Lien O. , Toften J.
Published: December 2007

Offshore locations, which use large diameter coiled tubing for wellbore intervention, are currently limited by the lifting capacity of the cranes on the platforms. Often intervention projects require a longer length of coiled tubing on a spool than can be lifted onto the platform. Historically this problem has been resolved by connecting two or more spools of coiled tubing on the platform with a butt weld. Safety considerations, logistical issues and repeatable low-cycle fatigue performance have made this practice undesirable.

Spoolable connectors have addressed concerns associated with butt welds, however limitations on connector fatigue life, elastomer durability and post connection integrity verification exist.

A mechanical spoolable connector and an assembly skid have been introduced in the North Sea. An integrity test verifies the tensile strength of the newly made connection. Testing has shown that the connector does not affect ballooning of the coiled tubing due to bending under pressure.

The assembly skid provides improved safety and efficiency when handling, preparing and installing a spoolable connector. Remote operation of the pipe handing equipment has removed the operator from the work area when pipe is moving, which reduces the exposure to this hazardous task. This equipment provides a safe work environment for efficiently handling and preparing the coiled tubing during the assembly and disassembly process.

The connector together with the assembly skid was used successfully on the Gullfaks B platform in the Norwegian sector of the North Sea for sand cleanout, scale milling and plug setting operations.
Comparison of Computation Fluid Dynamics of Slurry Flow in Coiled Tubing to Field Data
Authors: Blanco Ivan , Bailey Michael , Rosine Randy
Published: December 2007

Coiled tubing (CT) is widely used in well intervention as a practical and cost-effective means of servicing wells. Since CT's inception, the actual flow through CT has been a point of discussion and theory. Testing has been conducted to study what happens inside the CT. In recent years, the use of computational fluid dynamics (CFD) software has provided greater insight into actual CT flow patterns, including fluid-flow velocity profiles and secondary flow regimes. CFD helps to understand the fluid-flow phenomenon, which can lead to effective designs of friction-loss gradients. CFD has proven to be an effective alternative to full-scale testing.

The next development was modeling of actual field data from a fracturing service. This method compares predicted values, actual values, and computed values from the CFD solutions. CFD was used to provide correlations for the predictive model without full-scale testing, which greatly reduced the cost of development. Fluids investigated have included slurry pumped from an actual job.
Coiled-Tubing Fracturing on Slant-Well Operations
Authors: Pipchuk D. A. , Henriksen M. , Day M. , Boyko K. , Scott D.
Published: December 2007

The unconventional shallow gas market is the fastest growing oil and gas sector in Western Canada. Although these gas reserves are enormous, the economic output of a single well is marginal. The low production rate of each well has forced operators to reduce costs wherever possible. The largest expense in the completion of a well is stimulation. The advent of the coiled tubing fracturing method has reduced these costs substantially, as all zones can be individually isolated and stimulated in one operation.

Operators are taking further action by drilling multiple slanted wells from a single surface location. This configuration requires only one lease, one access road and reduces production costs with a single pipeline collection point. Workover equipment with the ability to rig onto these wellheads safely is in short supply. Many shallow gas wells utilize threaded wellheads that are not designed to support sideloads. Coiled tubing equipment is relatively massive, and previous attempts to ‘block up’ the wellhead and blowout preventers (BOPs) have resulted in near-tragic consequences. To overcome these obstacles, a patented support system capable of safe and efficient rig-up of BOPs on slanted wellheads was designed and built. The support system can be rigged onto wellhead angles ranging from 30-95 degrees. The system can manipulate the BOPs in virtually all planes to allow for flexibility when positioning onto a wellhead. The weight of the BOPs and CT equipment are then buttressed by the support system, and not the wellhead. The development of this system has enabled safe coiled tubing fracturing within the economic and technical contraints of shallow gas and coalbed methane type fields.
Coiled Tubing Becomes the Key Enabler for Successful Multilateral Well Development Campaign Offshore Brazil
Authors: Trummer S. , Silva D. , Cano V. , Guzman M. , Siqueira N. , Peixoto C. , Nazareth V.
Published: December 2007

Pampo was among the first producing fields offshore in Brazil, and it produced through a fixed platform. The maturation of the field and consequent decrease in oil production required a different completion strategy for the operator. The key reservoir, the Macae/Quissama, is the prime target for exploitation because it still has substantial oil in place, with good total recovery and actual recovery factors. The development of this reservoir was vital to the survival of the field

Several technical issues exist for developing this reservoir, especially during drilling, because of the high density of wells in the area. Each new well had to be carefully planned to avoid collision with existing wells and also to optimize the reservoir drainage. Several depleted wells have been evaluated to determine whether they should be abandoned and/or substituted.

There were limited options for replacing these depleted wells. With collision problems at shallow depth looming as a huge risk, the number of new wells that could be drilled was low. Furthermore, the lack of rigs available for production drilling and the high slot utilization on these platforms provided additional complications. Ultimately, the development of multilateral wells was identified as the most viable solution. From the main bore, once past the critical collision zone, several legs could be drilled to increase the drainage area.

Multilateral construction in this scenario is a nontrivial task. It requires the well junction to be placed at an area of high deviation, adding complexity for any intervention work. Nonetheless, the use of coiled tubing for most of the well completion operations proved to be the key enabler in this successful multilateral well development campaign. The versatility of CT technology significantly decreased the time needed for well completions and its other applications.

This paper discusses the development, planning, and preparation activities involved with use of the CT in this milestone project. It summarizes the results of the development of the idea and lessons learned from the numerous runs during the completions operation, including CT-conveyed perforating; CT-conveyed logging for cement evaluation; stimulation, featuring the use of isolation tools; and several Stiffline applications.