bluuebunny/crossref_metadata_2025 huggingface dataset:
Effective Application of an Innovative Conveyance Risk Management Methodology to Reduce Well Intervention Cost and Risks in Long/Deep/Tortuous Wells
Authors: Castillo H. C. , Wills P.
Published: December 2007

Some of the most important aspects to consider during the design, construction and productive life of a well are the amount and nature of the risks associated with the conveyance of downhole instruments to acquire critical formation evaluation (FE) data while the hole is open and downhole tool strings needed to service the well after installing the completion and production hardware.

With the increase in popularity of long, deep and tortuous wells, mainly in the high-cost operating environments, these risks have become more acute.

A new methodology, based on forces modeling and best practices gathered over decades, has been developed to take full advantage of new conveyance technologies intended to alleviate or eliminate these risks.

This paper describes the new conveyance risk-reduction technologies and their areas of applications, the newly developed risk management methodology and the economical value these innovations bring to our industry.

To demonstrate the merits and practical aspects of such an enterprise, we discuss here the following case study: A perforating job successfully completed using wireline and downhole tractors in a highly deviated well that was planned using the new methodology subject of this paper.
Spill Prevention, Control, and Countermeasure Plan Rule
Authors: Holliday George H.
Published: December 2007

The United States Environmental Protection Agency (EPA) promulgated the original Spill Prevention, Control and Countermeasure (SPCC) Plan rule in 1973. In 2002, EPA amended the rule, which became effective 16 August 2002. EPA postponed the revised rule compliance dates three times since promulgation and has proposed a fourth extension. In addition, EPA proposed and promulgated modifications to the revised rule to make the impact less severe on farmers, electric utilities, airport operators, and small businesses.

The rule modifications were promulgated 26 December 2006. Also, EPA proposed a new implementation date of 1 July 2009, but the implementation date of 31 October 2007 remains until the proposed revised date is promulgated. EPA states additional rule modifications will be proposed during 2007. Most businesses are reluctant to prepare SPCC Plans for facilities, since the contents of the final rule, if modified, are not known.

This paper reviews the 1) history of the SPCC Plan rule, 2) Agency's action to make the rule more palatable to a few selected stakeholders, 3) EPA modifications, 4) comments associated with the proposals to the EPA Dockets and 5) author's suggestions for compliance.
Bati Raman Field Immiscible CO2 Application: Status Quo and Future Plans
Authors: Sahin Secaeddin , Kalfa Ulker , Celebioglu Demet
Published: December 2007

The Bati Raman field is the largest oil field in Turkey and contains some 1.85 billion barrels of oil initially in place. The oil is heavy (12 °API) with high viscosity and low solution gas. Primary recovery has been inefficient, less than 2% of OOIP.

Over the period of primary recovery, from 1961 to 1986, the reservoir underwent extensive pressure depletion from 1,800 psig to as low as 400 psig in some regions, with a related production decline from a peak of approximately 9,000 Bbls/day to 1600 Bbls/day.

In March 1986, a CO2 injection pilot scheme in a 1200 acre area containing 33 wells was initiated in the west portion of the field. The gas injection was initially cyclic; "huff and puff" method was applied. Later, in 1988, the gas injection scheme was converted to a CO2 flood process. Later, the process was widespread to cover the whole field.

A peak daily production rate 13000 STB/d was achieved in 1993 in comparison to what would have been less than 1600 STB/d without CO2 application. However, since 1995, the field has undergone a progressive production decline to recent levels at approximately 5,500 Bbls/day. Polymer gel treatments were carried out to increase the CO2 sweep efficiency and arrest the decline. Multilateral and horizontal well technology was also applied on pilot scale to reach the bypassed oil. WAG is applied widespread now. Current production is 7000 Bbls/day.

This paper documents TPAO's 25+ years of experience on the design and operation of full field immiscible CO2 injection recovery project conducted in the B.Raman heavy oil field, in Turkey. The objective is to give an up-to-date status of the performance of the application; reservoir/field problems that TPAO had, unexpected occurrences and results and just a general idea of how successful the project has been.
Premobilization: Equipment Integrity Strategy for Safety Assurance in a Company in Nigeria
Authors: Gwaza Tersoo C.
Published: December 2007

The Lack of enforcement of Standards on equipments in the Developing World is a major challenge to the implementation of high safety standards with respect to equipment Integrity in the Exploration and Production business. A significant number of incidents in the last five years in the Shell Petroleum Development Company (SPDC) have been linked to Poor Equipment Integrity issues. The review of Incident statistics in the Company shows that one out of five incidents implicates equipment failure. SPDC has developed mandatory requirements known as Pre-Mobilization Procedures/Standards used in mobilization of high risk operational or contractual activity by the Company.

This paper discusses the pre-Mobilization process, a strategy used by SPDC to ensure personnel / equipment integrity and fitness for work before commencement and sustenance of same standards through activity/project life span and decommissioning.
Depth Conversion: Application of an Innovative Methodology: Added Value to a Fractured Carbonate Reservoir Interspersed With Tertiary and Mesozoic Salt Bodies Within a Very Complex Structural Setting
Authors: Flores Eduardo Lugo , Victoria Marcos , Roa Guillermo Sanchez
Published: December 2007

A Mesozoic mature oil field in Mexico's South Region shows a highly complex structural setting, salt tectonic has played a fundamental role in deposition and deformation, complex shaped salt bodies are present inserted within the tertiary and Mesozoic column. Several standard velocity modeling techniques have been applied in the field to depth convert the Cretaceous and Jurassic key stratigraphyc units. The most refined model showed in general 2D depth maps with an approximated prediction error of 200m.

To avoid shadow effects during the depth conversion process the interpreter has to extend the respective top and base of anomalous velocity bodies for the whole area of interest, it implies the building of fake horizons and a very time consuming grid merging process. The oversimplification of not considering those velocity anomalies embedded within the key zones implies the failure in the depth prognosis process.

The application of an innovative methodology helped to solve this problem. A 3D velocity grid is modeled considering the main structural and stratigraphyc features. Interval velocities from Seismic and from Check Shots are combined and populated. The anomalous velocity bodies are interpreted in the vicinity via manual tracking or seismic amplitude filtering. After being isolated, the bodies are related to different discrete properties as a facie, later the process of appending the connected bodies starts via conditional operations.

The result is a new Interval Velocity 3D grid that has considered the complex spatial geometry of high velocity shallow sands, as well tertiary and Mesozoic interspersed salt bodies. This Interval Velocity grid is vertically integrated and mathematically operated to be transformed into the Average Velocity 3D grid we used in the Depth Conversion process. Finally the error in the prognosis process is considerably reduced to a maximum of 100 m for wells with average total depth of 5000m.
Simulation Study of Drilling Horizontal Wells in One of Iranian Oil Fields
Authors: Azarkish Abbas , Khaghani Elham
Published: December 2007

The objective of this study is to investigate the advantages of drilling horizontal wells on oil recovery improvement. To evaluate the effect of horizontal length, porosity, anisotropy, staggered-line well pattern with gas injection (in the top layer) and water injection (in the bottom layer), different scenarios were studied.

This study is focused on simulation of formation-A of a carbonate reservoir which consists of three layers; where horizontal well is going to be drilled in layer-2 of this formation. The average thickness of formation-A is about 167.64 meters (550 feet) and we also have tilted water oil contact in this formation.

This field has produced around 146.9 MMBBL until year 2002 for the last 12 years with the Recoverable Reserve of about 237.31 MMBBL. Up to now 40 wells have been drilled in this field.

IRAP/RMS software was used to generate geological model. Based on selected reservoir black-oil model, IMEX from CMG is used for simulation task. Sector model used for simulation as we only had one productive horizontal well in the formation (scale-down method).

This study confirms simultaneous use of overbalance method and horizontal well in this reservoir in order to: A) Increase production rate up to 3 to 4.5 times by boosting productivity index (PI). B) Communicate a large area leading to a better drainage area. C) Postpone the water breakthrough by minimizing the draw down pressure.
Kuwait Employs Underbalanced Drilling Technology To Improve Drilling Performance While Simultaneously Evaluating the Reservoir
Authors: Vieira P. , Larroque F. , Al-Saleh A. M. , Ismael H. , Qutob H. H. , Chopty J. R.
Published: December 2007

The Shuaiba formation is a highly fractured limestone reservoir. The use of conventional overbalanced drilling technology in this formation usually results in the complete loss of drilling fluids to the formation. These losses cause drilling problems and results in the masking of the potential for hydrocarbon production. Underbalanced Drilling Technology was proposed as an alternative drilling method in order to evaluate the Shuaiba formation for producible hydrocarbons while simultaneously eliminating fluid loss to the formation and improving drilling performance.

The Shuaiba formation was successfully drilled underbalanced without any fluid loss during the drilling phase and a successful evaluation of the formation for hydrocarbons was completed for the first time. A multidisciplinary team contributed to the engineering, planning and execution of the first underbalanced drilling operation in Kuwait. This paper highlights the key factors in the underbalanced drilling design phase and the operational results of the first well drilled in Kuwait using underbalanced drilling technology.
Kuwait Employs Underbalanced Drilling Technology To Improve Drilling Performance While Simultaneously Evaluating the Reservoir
Authors: Larroque F. , Al-Saleh A. M. , Ismael H. , Qutob H. , Chopty J. R. , Vieira P.
Published: December 2007

The Shuaiba formation in the Raudhatain field is a highly fractured limestone reservoir. Conventional drilling technology in this formation usually results in a complete loss of drilling fluids to the formation. These losses cause severe formation damage which results in masking the evaluation of the potential for hydrocarbon production.

Underbalanced Drilling Technology was proposed as an alternative drilling method. The main objective of the UBD drilling application was to evaluate the potential of hydrocarbon in the Shuaiba formation while simultaneously eliminating fluid loss to the formation and improving drilling performance.

This well was the first well drilled underbalanced by KOC, a training program was prepared in order to familiarize the rig personal involved with the operation of the UBD equipment and procedures. The openhole section was drilled out of a 10 ¾" casing with an 8 ½" bit. A conventional mud pulse MWD/PWD/LWD tool with real-time annular pressure, temperature and gamma ray sensors were incorporated in the BHA. The use of MWD/PWD/LWD provided a means of monitoring the downhole underbalanced conditions and formation properties while drilling. The Shuaiba formation was successfully drilled underbalanced without any fluid loss during the drilling phase. The openhole section was drilled to a total depth (TD) of 8942 ft MD, with an openhole length of 242 ft.

Integrated efforts of KOC and service companies of various disciplines during planning and operation stages of the well led to the success of the project. No QHSE incidents were reported.

This paper highlights the key factors in the underbalanced drilling design phase, the operational challenges faced, and the results of the first well drilled in Kuwait using underbalanced drilling technology.
Prevention of Back Injuries: Using an Ergonomic Evaluation Team To Customize Training and Identify Improvement
Authors: Disatell Joel , Knode Tom
Published: December 2007

Back and hand injuries are among the most common types of injuries that occur while engaging in pressure pumping at the wellsite. This is not surprising given the heavy iron that must be lifted off trucks, carried into position, and then connected using hammers. The challenge is to implement engineering and human factor controls to minimize risk to employees.

This question was posed to an outside group of ergonomics experts. Consultants were used because their opinions were less likely to be biased by potential preconceptions of those working around the hazards for years. These consultants were requested to evaluate the ergonomics of rigging up, running a job, then rigging down pumping equipment. They visited wellsites and witnessed a variety of locations and job types.

Based on the prioritized conclusions of the ergonomists, a customized back-safety training program has been piloted to address body mechanics. The study has also led to the identification and sharing of best practices for equipment design. It also resulted in the creation of a prejob preparation video that highlights stretching exercises that should help reduce the potential for injury. Preliminary results of the pilot program are encouraging.
Information Architecture Strategy for the Digital Oil Field
Authors: Burda Barbara , Crompton Jim , Sardoff Hugh , Falconer John
Published: December 2007

Digital Oilfield (i-field) technology is based on both new and existing IT platforms. Development of new tools that require a new approach to architecture has presented numerous pilot project opportunities. These pilot projects have uncovered at least one common theme revolving around the quality and completeness of local information management solutions and the difficulty of integrating new solutions into legacy applications and work processes.

Chevron's Global Upstream (Chevron) has initiated an IT program, named Level 0, to provide the technology platform for integration to drive performance improvements prescribed by i-field, base business and reservoir management initiatives. In many cases, current state information stores, applications solutions and field infrastructure are aligned with traditional functional requirements but do not easily integrate to provide a broad perspective for full asset management. The Level 0 effort is taking an approach to provide an enterprise solution through distributed efforts coordinated through corporate IT support functions.

Oil and gas production environments are diverse. Requirements in a heavy oil environment are vastly different from i-field deliverables in an offshore setting; however, they may interact with core IT systems in a similar manner. To maximize re-use of common functions and allow for priority functionality development, Level 0 teams are building a consistent information architecture, web service/interoperability architecture and real-time data architecture. Details of these architectures are being built independently by the co-located project teams but are using common technology and philosophical approaches.

Chevron Upstream Europe (CUE) and San Joaquin Valley Strategic Business Unit (SJVSBU) are the first two business units to engage in this program. CUE has proven the technology solutions and information architecture are sound. SJVSBU is widening the scope to provide additional functionality. The next wave of Level 0 projects are starting up in our Gulf of Mexico and Mid Continent business units. Agile Scrum methodology, a methodology based on short development intervals called sprints, is being utilized by both current projects. This methodology allows scoping and delivering architectural extensions or application functionality every 30 days. Processes to insure evergreen alignment of extensions are being formalized.
Viscosity Prediction of Crude Oils with Genetic Algorithms
Authors: Hajizadeh Yasin
Published: December 2007

Modern reservoir engineering practices require accurate information on thermodynamic and transport fluid properties together with reservoir rock properties to perform material balance calculations. These calculations lead to the estimation if initial hydrocarbons, the future reservoir performance, optimum production schemes and ultimate hydrocarbon recovery. These fluid properties which are usually determined by laboratory experiments or using empirically derived correlations provide the information required to properly understand the phase behavior, evaluate various production scenarios, optimize reservoir production and IOR schemes, and to maximize ultimate recovery and optimize production economics. One of these properties is the petroleum reservoir fluid viscosity. Crude oil viscosity is an important physical property that controls and influences the flow of oil through porous media and pipes.

This paper introduces a new implementation of the genetic algorithms technology in petroleum engineering. Intelligent techniques such as genetic algorithms for data analysis and interpretation are an increasingly powerful and reliable tool for making breakthroughs in the science and engineering. The introduced model in this paper can predict the reservoir fluid viscosity data with genetic algorithms technique.

Prediction results of the proposed model have been tested against the measured reservoir fluid viscosity data. Results indicate that the proposed prediction model can successfully predict and model reservoir fluid viscosity.
Enhanced Thermal Desorption Process Can Extend Life of Base Oil and Reduce Energy Costs
Authors: Fang Cindy C. , Oronite Chevron , Seaton Simon , Shumway William
Published: December 2007

In many cases, the primary waste management challenge facing operators is drilled cuttings generated using oil- or synthetic-based fluids (OBF, SBF). Low temperature thermal desorption units (TDUs) are commonly used treatment systems for removing oil from cuttings. The oil recovered from the thermal desorption process is often reused to make oil-based fluids. However, base oils change during the thermal desorption process, and these changes can have a detrimental impact on the performance of the base oil. In some cases the base oil can break down.

Typically the base oil used to formulate an OBF or SBF is selected for economical, drilling and logistical reasons and rarely, if ever, the thermal properties of the base oil. The thermal treatment company is left to determine how best to recover the oil so that the thermal degradation is minimal and the oil is suitable for reuse. To lower energy consumption and preserve the performance of the base oil, it is important to identify a base oil that has either a lower temperature for desorption or higher resistance to thermal degradation during the thermal desorption process. Ideally, a base oil would be chosen that incorporated both properties. The results of this study show that by correctly evaluating and selecting the base oil, the operator can benefit from using a fluid that may be much more suitable for reuse and will require much less energy to thermally treat.

This paper describes how to achieve both of these goals using Thermal Gravimetric Analysis, Gas Chromatography / Mass Spec and a low-temperature retort. Determining the optimal desorption temperature is also an important factor. The oils recovered using these methods contain no oxygenated products and exhibit little thermal degradation. Residual oil from on cuttings is less than 1% (w/w). A practical methodology for base oil selection also is included in this discussion.
Maintaining Observer Skills Through an Effective Coaching Structure
Authors: Whitney Paula , Schafer Harold Christian
Published: December 2007

Behavior observation and feedback processes change behavior in two ways: by giving feedback to workers immediately after an observation and through the development of improvement plans that utilize the data captured during the observation. If the quality of the feedback given to workers is poor or the quality of the data captured deficient, the effectiveness of the behavior-based safety (BBS) process will be compromised.

Observer coaching can be used to build and maintain observation skills. Coaching is applied in the same way as observations, by providing feedback immediately after the observation. It reinforces behaviors performed correctly and highlights potential consequences of incorrect behaviors. Coaching feedback is most effective when it happens soon after the observation occurs and when it is conducted in a positive manner. Immediate, certain, and positive coaching feedback acts as a reinforcement that can both build observer skills and motivate observers to perform more observations.

The steering team, a group of employees who own the BBS process, should develop the coaching process and structure. Results from the implementation of a coaching process in a large organization have demonstrated improvements in observer participation and an increase in the number of observations. Observation quality has also improved as a result of the maintenance of observer skills and controls put in place to help ensure good quality observations.

Coached observers develop feedback communication skills needed to change behavior and writing skills needed to document observations accurately. Good written documentation, or observer commentary, is needed to help ensure that high quality observation data is available for action planning. Use of observer coaching is an effective way to help ensure the high quality needed to maintain a strong and healthy BBS process.
The Development and Trial Use of Oil Exploration Drill-Cutting Waste as an Aggregate Replacement in Cold-Mix Asphalt
Authors: Allen Bob , Day Dennis , Armstrong Stephen , Page Paul , Murdoch Keith , Beardsley Ron
Published: December 2007

The safe disposal and minimisation of offshore drilling waste has been a major environmental concern for the petroleum industry over many years. This paper presents the collaborative work between; oil drill cuttings generator, road authority and asphalt technologists to produce a cold mix asphalt solution to the problem of disposal.

The drill cuttings are high in moisture content and contain some hydrocarbon residues, the preliminary design identified that the addition of drill cutting waste into asphalt reduced the stiffness and inherent stability of the mixtures examined.

These two problems were overcome by redesigning the binder and by replacing up to 20% of the virgin aggregate with incinerator bottom ash. Use of the ash increased the aggregate pore structure within the mixture and accommodated the relatively high moisture contents whilst the binder modification allowed for the inherent low viscosity oils.

The project concluded with a plant/quarry trial of the Laboratory developed mixture to assess suitability for full scale production and any eventual application. This process promises to be an effective method of reducing offshore drilling waste in a cost effective and environmentally sound way.
Implementation of a Management System Execution Framework To Establish a Culture of Accountability and Improved Safety Performance
Authors: Cadigan Michael F. , Stough Joe
Published: December 2007

A management system is a company's corporate-wide standardized framework of processes and practices used to ensure that an organization can fulfill all tasks required to achieve its objectives. For example, an operational excellence management system provides standardized guidelines and practices to enable continuous improvement of the organization's operational risk mitigation competence. The simplest frameworks include the ability to execute – "Plan, Do, Check, Act." A more complete management system would include accountability and a schedule for activities to be completed, as well as auditing tools to implement corrective actions in addition to scheduled activities, creating an upward spiral of continuous improvement facilitating operational risk management across the enterprise.

As a startup drilling contractor, implementing a management system and defining a corporate culture can be a daunting task. Part of the culture that must be nurtured is an environment of accountability. One such contractor, hereafter known as the "Company" employed a preferred practice enterprise risk management tool already utilized by many major operators. The idea is simple; develop a culture of accountability by using proven business processes already employed by many major operators. Starting with a small scope of functionality using incident reporting and action item tracking, this Company has formed the backbone of a true accountability system. With initial success in tracking closure of action items, the Company is now posed to expand the tool with dedicated modules to govern other processes within the management system including:

Management of Change Training Requests Audit/Assessment Module High Value Learning Events Behavior Based Safety Observations Health, Safety and Environment (HSE) Metrics

Many companies use different software technology toolsets to strengthen their execution of various management system processes with the goal to reduce costs incurred from loss events (injuries, spills, asset damage, operation shut-downs, etc.) on a global scale. A successful management system framework should enable transparency and accountability across all facets of the organization using centralized tools.

Many of these management systems have similarities and a common intent. However, often the case is management systems exist in the form of three-ring binders that sit on the shelf and therefore scarcely reflect the realities of how business is run in the field.
Worldwide Coalbed Methane Overview
Authors: Chakhmakhchev Alex
Published: December 2007

Recent coal bed methane (CBM) success in North America has been due to a number of coincidental factors such as the existence of extended coal basins, strong gas prices, a dense distribution network, and little competition with declining conventional gas production. Strong demand for both oil and gas is pushing the rest of the world (especially Australia, China and India) to speed up CBM developments. However favorable geological factors such as occurrence of thick gas-rich coal seams with good porosity/permeability characteristics do not necessarily coexist with an ideal business environment in many of these countries. Outside of the North America, Australia has the most commercially advanced CBM industry. The country contains about 30 coal-bearing basins, mostly Permian and Mesozoic in age. Based on IHS data, proven reserves in Australia have been estimated at nearly 9 tcf. In China, an estimate size of CBM resources is very impressive at about 1,200 tcf. The question is: What portion of these resources is commercially recoverable? Today most of the CBM projects in China are in exploration or initial development phases. Key International CBM players in China are Chevron, Greka, BP, Far East Energy, ConocoPhillips and Canadian companies - Terra, Ivana, Verona. India is also making an effort to attract both local and international companies to explore CBM potential in the country. Three bid rounds held in 2001, 2003 and 2006 were successful. Under the latest 2006 bid round, CBM exploration blocks were awarded to Australian, U.S. and European companies. Indonesia is currently preparing new legislation regarding the exploitation of CBM. The new legislation is expected to be completed in 2007. The government had been expected to open to tender the first acreage specifically designed for CBM exploration and production in order to exploit Indonesia's as yet untapped resources of CBM, estimated at 453 tcf. Both Vietnam and Mongolia signed CBM contracts with Canadian companies. Definitely these countries have geologic potential for CBM, however, lack of infrastructure and uncertain gas price raise many questions. From a commercial standpoint, West Europe is favorable for CBM developments; however, environmental issues and lack of gas-saturated coal seams extended over large areas may slow down full-scale production from coal beds. Much less is known about CBM potential in Eastern Europe including Poland, Romania, Ukraine, and Bulgaria. In several Latin American countries CBM exploration efforts are in their initial phases. Some countries are offering incentives to CBM investors, which make CBM exploration and production a feasible alternative to conventional gas. On the other side, there are fiscal regimes designed for conventional hydrocarbons that do not provide investors reasonable returns under traditionally low gas prices in those countries.
Introducing Predictive Analytics: Opportunities
Authors: Stone Paul
Published: December 2007

Energy companies' data bases hold the potential for tremendous advantage. Moreover, they are growing exponentially, fed by a mounting array of sources including ERP systems, sensory networks, machine instrumentation, credit card transactions, loyalty programs, and increasing multi-media and other unstructured data. Yet analyzing and extracting value from large datasets has always been a problem due to the sheer volume of data and consequent "signal to noise" problems.

To unlock some of this value, BP have launched a "predictive analytics" initiative, investigating pattern recognition techniques that find correlations and relationships in large datasets. This form of analysis is not new, but pilots in previous years have not resulted in significant implementation. However, recent advances in computing power coupled with more sophisticated applications, easy-to-use interfaces and easier access to data, have made predictive analytics a more valuable, practical tool for wide scale corporate adoption. And now, with more data available from sensor enabled applications, predictive analytics presents an opportunity to make all aspects of our field operations more efficient and effective.

A particular distinction of these techniques is that the models used are data-driven, and do not rely on a fundamental understanding of the first principles involved. This means that predictive analytics can be particularly useful where the underlying scientific principles are complex and difficult to model precisely. Data driven models can be created with reduced effort and often without the need for in-depth skills used to create models from first principles.

To take advantage of these techniques, the Digital & Communications Chief Technology Office (CTO) has been leading a program to introduce predictive analytics across all business segments and operations in BP. In so doing, we have been working closely with our segment specific technology teams, FIELD OF THE FUTURE, Refining Technology and our Exploration and Production Digital & Communications Technology teams. Having established connections with over 50 "predictive analytics" vendors, CTO is working with business units and functions and have completed a number of proof of concept (POC) trials utilizing a variety of innovative vendor solutions

This paper describes a number of these POCs and presents the value proposition for data driven predictive analytics.
Ultradeep Extended-Reach Stimulations
Authors: Tongs Taylor , Hinrichs Angela , Spickett Rae , Robertson Les
Published: December 2007

Recent advances in drilling technology have resulted in longer horizontal wells being drilled to more efficiently exploit reservoirs. However, these long open hole horizontals are often problematic when using coiled tubing as the well intervention conveyance system during stimulation.

Coiled tubing, a commonly used intervention tool for open hole horizontals, is considerably less stiff than jointed drill pipe and cannot reach TD on many wells due to friction. Assistance from friction reducers, well tractors or other devices have helped, but can be potentially damaging, expensive and/or high risk.

This poster details the use of a simple agitation tool placed in the coiled tubing bottom hole assembly during the stimulation. This results in decreased friction which in turn increases reach for coiled tubing thereby allowing full horizontal open hole stimulation treatment.

The case study that is presented on the performance of the agitation tool used in coiled tubing stimulations in long horizontal open hole sections of a hot, sour reservoir with a total measured depth up to 7 kilometers.

Suncor Energy has utilized this process in the development of its Panther River reservoirs in the Western Canadian Sedimentary Basin with excellent results. Benefits discussed include reduced completion cost and reduced environmental impact.
Innovative Horizontal Water Injector Completion Improved Wellbore Accessibility and Enhanced Well Control
Authors: Al-Amer A. A. , Al-Sowayigh M. I. , Al-Mumen A. A. , Al-Zain A. K.
Published: December 2007

Drilling of horizontal oil and water injection wells in Saudi Aramco is rapidly increasing. Ensuring the optimum completion for all types of wells, and in particular water injectors, is essential for rigless intervention work such as stimulation, logging using Coiled Tubing (CT) and installation of mechanical downhole isolation barriers for rigless wellhead repair. A typical horizontal water injection well is usually completed with 3000' to 7000' open hole horizontal section and a tubing string that extends below the last casing. The tubing string is packerless and is installed as a CT guide for intervention work to bypass washouts below the casing shoe. This completion introduces well control challenges in case of rigless wellhead repairs especially in high reservoir pressure areas, where the minimum requirement for well control is two isolation barriers. The standard completion can not accommodate this requirement. The only alternative for the rigless wellhead repair is mobilizing a rig to perform the required work. This option is very expensive. An innovative completion for horizontal water injection wells has been recommended and implemented to achieve two main objectives: first to alleviate well control issues by allowing at least two shutoffs to execute rigless wellhead repair or replacement and second to facilitate accessing the wellbore, in case of formation washouts below the last casing shoe, with CT for intervention work. This paper covers completion background for horizontal injectors and challenges to optimize downhole completions to overcome limitations. Also, discussion of the collaborative work among various Saudi Aramco organizations and Service Companies in deploying this innovative completion will be presented. This success story of using this modified completion will illustrate Saudi Aramco's determination to overcome challenges and introduce best completion practices.
Mercury Monitoring and Removal at Gas Processing Facilities
Authors: Abu El Ela M. , Mahgoub I. S. , Nabawi M. H. , Azim M. Abdel
Published: December 2007

Khalda Petroleum Company (an international joint venture company in Egypt) has recently found Mercury as a naturally occurring component of geological derived hydrocarbons in the Western Egyptian desert. Since then, Khalda Petroleum Company has concentrated on measuring and removing of the mercury from its produced gas. A mercury removal unit was installed at Salam gas processing plant. The mercury contents of the gas at the inlet and outlet of Salam mercury removal unit have been continuously monitored. This paper covers the process design, the field analysis procedures, and the performance of the Salam mercury removal unit. Such study is an original contribution to the knowledge of mercury problems in the gas industry and the technologies used for mercury removal.
From Sensors to Models to Visualization—Handling the Complex Data Flow
Authors: Kolnes Ø. , Kluge R. , Halsey G. W. , Bjørkevoll K. S. , Rommetveit R.
Published: December 2007

The paper describes the underlying infrastructure of an advanced real time integrated drilling simulator that is under development. Focus will be on handling the complex data flow and meeting the requirements regarding simultaneity when designing such a compound system.

A synthesis of multiple transient and steady state models for drilling sub-processes with links to 3D visualization software and measured data is being built on the technology described in this paper. Possible applications include: personnel trainingtesting and comparing drilling plansreal-time diagnosis: warnings, optimization and forward lookingprocess controlpost analysis

This paper describes several challenges when developing a compound system for data processing in networks. For example the system must: be designed to function with a degree of sensor failuremake both measured and predicted values availablemake historical data available for the entire wellmake auxiliary data (rig, formation) availableallow for synchronization of measurements and predictions in timemanage task co-ordination between modulesmanage storage and retrieval of user communication

The paper discusses different approaches to the challenges presented and recommends solution strategies.

The underlying infrastructure is a crucial part of an integrated drilling simulator. It is the core of a technology that allows better utilization of drilling data through easier data access, visualization and advanced modeling. Such a system is an important element in integrating operations and enabling better communication between distributed experts.
Natural-Disaster Preparedness: Best Practices
Authors: Perdue J. M. , Divakaruni S. M. , Russell C. , Johnson C. , Dowden C. , Kaleda P. , Haran E.
Published: December 2007

Following the 2006 Digital Energy Conference with its stimulating Lunch & Learn session on "Hurricane Preparedness," the SPE Gulf Coast Section's Digital Energy Study Group formed a Working Group to collect lessons learned during Hurricanes Katrina and Rita, which had a disastrous impact on the oil and gas industry along the U.S. Gulf Coast. Composed of crisis team leaders and business continuity professionals from major oil companies, independents, oilfield service companies and communications providers, the Working Group sought to identify a number of better practices to share with the global oil and gas industry in the form of a White Paper. This SPE paper is a synopsis of the better practices captured during three Working Group meetings, at which companies shared their Hurricane Katrina and Rita experiences and subsequent improvements they made to their natural disaster preparedness programs. These recommendations are consistent with the professional practices of both the Disaster Recovery Institute (www.drii.org) and the Business Continuity Institute (www.thebci.org). In most cases they provide an additional level of industry-specific detail to established practices.
New Flow Regimes for Well Near Constant Pressure Boundary
Authors: Sui W. , Mou J. , Bi L. , Deng J. , Ehlig-Economides C.
Published: December 2007

Recent studies have shown field data exhibiting a negative half slope trend in the pressure derivative that cannot be explained as spherical flow. In one case the well was located in an elongated fluvial reservoir bounded on one end by an aquifer acting as a constant pressure boundary. In another case the well was also in an elongated reservoir, this time crossed by a highly conductive fault. None has shown a rigorous derivation for the analytical equations for this flow regime.

This study derives flow regime equations for two new flow regimes encountered by a well near a constant pressure boundary. When there is no evidence of another nearby boundary, the pressure derivative trends are radial flow until the constant pressure boundary is encountered, and after that a straight trend with negative unit slope is observed. This flow regime is named here as dipolar flow. When the well is in an elongated reservoir near a constant pressure boundary perpendicular to the elongated direction, possible flow regimes include radial, dipolar flow, linear flow, and a flow regime with negative half slope, which is named here as dipole linear flow.

Normally falling derivative behavior due to a constant pressure boundary is assumed to signal the end of any useful parameter estimation, but the new dipole flow regimes are sensitive to permeability and to the distances to the constant pressure boundary and to boundaries defining the elongated reservoir. This study shows how to use the flow regimes to determine distances to closed and constant pressure boundaries, and to identify bedding plane permeability anisotropy (kx from well to constant pressure boundary, ky parallel to constant pressure boundary plane). The new flow regimes are present in standard single fault and rectangle models for pressure transient behavior, but they have never been rigorously derived or described.
Effects of Friction in Drain Hole on Productivity of Horizontal and Multilateral Wells
Authors: Guo Boyun , Zhou Jinkui , Ghalambor Ali
Published: December 2007

It is generally recognized that most horizontal wells do not produce oil and gas at the expected production rate. The discrepancy can be attributed to several factors including reservoir heterogeneity and non-perfectly horizontal wellbores. This study reveals that the frictional pressure loss in the horizontal drain hole is a key factor affecting inflow performance of highly productive and small-diameter and/or long horizontal wells.

By rigorously coupling reservoir inflow and drain hole hydraulics, equations for pressure distribution in the horizontal oil and gas drain holes were first derived in this study. Simple functions for oil and gas flow rate profiles in the drain holes were then developed. Equations for deliverability of horizontal oil and gas drain holes were obtained by evaluating the flow rate functions at the heels. Sensitivity analyses with the equations indicate that neglecting the frictional pressure losses in the horizontal drain holes can cause over-estimate of well productivity by 30 % in highly productive reservoirs and by 50% in small and/or long horizontal wellbores. This paper provides petroleum engineers a simple tool for accurately predicting productivity of horizontal and multilateral wells.
Simultaneous Acid Diversion and Water Control in Carbonate Reservoirs: A Case History From Saudi Arabia
Authors: Al-Taq Ali A. , Nasr-El-Din Hisham A. , Beresky Jimmy K. , Naimi Khalid M. , Sierra Leopoldo , Eoff Larry
Published: December 2007

Acid diversion and water control are usually addressed as two separate issues. Associative polymers can be used to simultaneously achieve effective diversion and water control during a single treatment. A polymer-based treatment was applied in an offshore, perforated vertical well with two sets of perforations in a carbonate reservoir in Saudi Arabia. The acid treatment was needed to restore the productivity of the upper set of perforations and reduce water production from the lower set of perforations.

Experimental studies were carried out to investigate the potential use of associative polymers to control water mobility and act as an acid diverter. Coreflood experiments were conducted on reservoir cores at downhole conditions (temperature of 200°F and pressure of 3,500 psi). Extensive lab testing showed that associative polymers had no significant effect on the relative permeability to oil. However, the relative permeability to water was significantly reduced.

This paper presents a case history where an associative polymer was applied during matrix acid treatment of a damaged well. The treatment included stages of associative polymer solutions and 20 wt% HCl with additives. Post stimulation treatment production data showed that oil rate increased by 11-fold; whereas water rate decreased by 3-fold; resulting in a reduction in the water-cut from 75 to 14 vol%. The PLT test confirms that the associative polymer was very effective in diverting the acid to the oil zone. The PLT showed that the upper set of perforations was producing most of the fluid, which further confirmed that the associative polymer was effective in reducing the relative permeability to water.
Successful Application of Integrated Digital Automation System for Production Optimization in the North San Juan Basin
Authors: Oyewole Peter O. , Scull Michael D. , Downey Mark S. , Herring John B.
Published: December 2007

An integrated digital automation system has been used successfully to efficiently optimize tubing flow control and plunger lift installations in North San Juan basin. This paper presents description, application, and significant results achieved by using an intelligent closed looped digital integrated automation system. Results included increased gas production, equipment reliability, also, efficient and inexpensive deliquification method through almost exclusively remote-controlled operations.

The smart digitally enhanced system consists of two parts; the Remote Terminal Unit (RTU) and the SCADA-host. The common RTU application is deployed across all well sites and utilizes a common application load. Where and when needed, new feature selections have been added however complete backwards compatibility has been maintained. This is made possible mainly by abstracted I/O and a modular programming technique. The SCADA-host which is also a common unifying system provides interface to all wells for surveillance, monitoring and control capability. The system displays the current system layout graphically. Historical trends are also easily retrievable.

Gas production increment of over 4MMcfd has been achieved and sustained in less than 40 plunger lift installations mainly due to availability of high quality digital automatic control system coupled with effective utilization of plunger lift data. By itself, the system adjusts plunger arrival time, after flow and shut-in time based on pre-set operating range to maximize gas production. Thirty tubing flow control installations have resulted in an average gas production uplift of 130Mcfd per well. In tubing flow control application, the casing valve is automatically controlled based on well conditions. This allows a well to flow gas through tubing above critical gas rate while releasing friction and backpressure on the formation by producing additional gas through the tubing-casing annulus. It is a simple process that includes a combination of surface equipment and control logic that could not perform faultlessly without intelligent automation system.

This is a significant departure from the traditional means of operating gas wells where highly expensive full rig intervention is required to continuously optimize tubing size and artificial lift installation. As expected, improved business performance has been achieved through an intelligent integrated digital automation system.