bluuebunny/crossref_metadata_2025_split huggingface dataset:
Developing the Micro-Flux Control Method—Part 1: System Development, Field Test Preparation, and Results
Authors: Santos H. , Reid P. , Jones J. , McCaskill J. 
Published: December 2007

Abstract
The paper presents the first part of the development of a closed loop drilling system for the management of downhole pressures. It is based on the Micro-Flux Control (MFC) method and uses real time simulation techniques connected to a process control loop that facilitates full back-pressure control over the well. The method has been described previously and is only briefly summarized here.
This paper reviews the challenges and development hurdles that were overcome to commence field testing of the MFC method. The paper also describes how the first version was defined, based on feed-back received from operators, service companies and equipment suppliers.
A combination of established field-proven UBD technology and existing conventional drilling techniques are used, integrating with a software-based well control system. This allows the operator to maintain an effective, safe, on-line watch on the well control process at all times and in real-time.
The paper describes the results of the first series of tests conducted at a test well facility, where influxes were detected and automatically controlled with less than 1 bbl of pit gain. These outstanding results confirmed the ones previously obtained using a full size drilling simulator in the first part of the development; these results are also presented in the paper.
The paper finally describes the next steps to be taken for the system to become fully available for application in a wide range of wells.
Life-Cycle Profile Control in Subhydrostatic Wells of South Oman
Authors: Ojukwu K. I. , Mueller K. , Murshidi A. , Masroori M. , Edwards J. , Tramaille D. 
Published: December 2007

Abstract
Profile modification of injection and production wells is of major importance in South Oman heavy oil reservoirs. This is because injected and produced water must be controlled to optimize reservoir sweep and oil production.
Profile control in artificial lift wells is also a common dilemma because the intervention involves re-completing wells to achieve logging-while-pumping necessary for detecting unwanted intervals.
In 2004, two completion philosophies were adopted to allow hoist-free re-entry as well as provide a cost effective life-cycle solution. One is the replacement of smart wells with segmented horizontal wells. This completion allows for effective diagnosis and isolation of watered-out sections. The other is replacing the upper completion of producers in sub-hydrostatic reservoirs with dual Christmas Trees. That makes it possible to measure the inflow profile while pumping through the second tubing.
A proactive measure was taken by field-testing a new technology capable of satisfying all basic requirements. The technology is a wireline deployed rubber and carbon fiber sleeve expanded by hydraulic pressure to set flush against the casing. Heat is applied to polymerize the resin before deflating and retracting the running tool. The patch thickness can withstand both burst and collapse pressures, leaving sufficient internal-diameter in 7-in and 4 ½-in casing for subsequent deeper intervention.
Phase-1 trial was successfully completed in 3 water injectors late in 2004. Phase-2 trial which was planned for 2 oil producers are still being mobilized and will be executed in third quarter of 2005, late for publication in this paper.
Some unique characteristics of this technology made it attractive; namely (1) ability to deploy via smaller size tubing to expand & set in larger perforated liners, thus eliminating rig/hoist requirement, (2) high depth precision using CCL correlation, (3) possibility of bypassing existing patch to isolate downstream toe area, (4) possibility to by-pass isolated areas to re-perforate lower zones and safely retrieve the bloated gun barrels, (5) applying gentle and even hydraulic force contour-to-contour to set against un-reinforced liners, (6) cost effective solution of higher success rate compared to chemical treatments. The trials proved to be the first campaign of its kind to be successfully completed with 100% success rate, while meeting all expectations.
Aluminum Alloy Tubulars for Oil And Gas Industry
Authors: Gelfgat M. Y. , Basovich V. S. , Adelman A. 
Published: December 2007

Abstract
Oil and Gas industry requires a significant amount of tubular goods to meet their operational objectives. Drill pipe, casing, tubing and risers must be designed and manufactured to accommodate present and future tendencies of drilling deeper, longer, faster and more efficiently while maximizing production for every well drilled. The most important feature of aluminum alloys used as materials for tubular manufacturing is that they provide exceptional strength-to-weight ratio. This simply means that the length of aluminum alloy pipe string suspended under its own weight would be about two times longer than steel. This feature allowed development of aluminum drill pipe which has an excellent potential in extended reach drilling of wells of 15 km long. The last five years of field applications in West Siberia have proven that ADP has high reliability and life expectancy. Equally superior performance is projected for aluminum casing, tubing, and line pipe. Use of aluminum drilling riser strings in deep waters of offshore Brazil and GOM helped to establish that aluminum alloy is very reliable construction material for some of the most difficult applications in the petroleum industry. This experience provides us with confidence in continuing to develop new products for the industry, such as completion and production risers.
Young Resources in the E&P Industry: Key Issues to a Successful Start
Authors: Bruni T. , Tealdi L. 
Published: December 2007

Abstract
It is in the very early time of one's employment that many decisions, both from the company side and the employee's side, are taken that will significantly impact the individual's career and professional development. This first phase of any anyone's career is hardly ever one during which major/actual work is carried out by the new hire. For non-experienced employees, in most large/major E&P companies, this induction period is mainly focused on training which is widely recognized as carrying vital importance, as it guarantees the safeguarding and perpetuation of the company most precious asset: that of a competent and skilled workforce. In the oil business, many "intangibles" like the employee potentials and competence are a critical factor for success and an important source of competitive advantage for the companies. With the exception of very few employers, the induction period is often organized in a "static" manner, without much opportunity to for tailoring the program based on the employee's feedback. This poses potentially dangerous consequences that might finally result in a missed chance of realizing the full potential of the young resource and, in some cases, in the loss of talents that represent an important strategic asset for the companies.
The paper presents a new approach to the development of young resources, and it encompasses several themes revolving around training, potential and how to realize all of the value residing in the human resources.
Development and Application of New Downhole Technology To Detect Water Encroachment Toward Intelligent Wells
Authors: Jackson M. D. , Saunders J. H. , Addiego-Guevara E. A. 
Published: December 2007

Abstract
Electrokinetic potentials are generated when fluids flow through rock. We have investigated whether changes measured in electrokinetic potential using permanently installed downhole electrodes could be used to detect water encroachment towards intelligent oil wells. Downhole electrodes in cemented arrays have been successfully utilized in resistivity measurements, but have not previously been used to measure electrokinetic potential. One reason is that it has not been possible to relate changes in potential with changes in saturation. We have reviewed the existing literature and conducted laboratory experiments to determine how the electrokinetic potential varies with water saturation, brine salinity and other key reservoir parameters.
We have used the results to simulate numerically the electrokinetic potential response measured at a well during oil production. Preliminary results suggest that encroaching water causes changes in the measured electrokinetic potential which could be resolved above background electrical noise; indeed, water could be detected several 10's to 100's of meters from the well. We have also investigated the optimum response of an intelligent well equipped with downhole inflow control valves. In a simple, conceptual reservoir model, production is significantly enhanced if encroaching water is detected before it arrives and flow into the wellbore is properly controlled.
Our findings raise the novel prospect of an oil field in which the wells can detect the approach of water and respond appropriately. Such wells offer enormous potential economic and environmental benefits, particularly in fields which are difficult to access or dangerous to operate.
Modeling Permeability in Coal Using Sorption-Induced Strain Data
Authors: Robertson E. P. , Christiansen R. L. 
Published: December 2007

Abstract
Sorption-induced strain and permeability were measured as a function of pore pressure using subbituminous coal from the Powder River basin of Wyoming, U.S.A. and high-volatile bituminous coal from the Uinta-Piceance basin of Utah, U.S.A. We found that for these coal samples, cleat compressibility was not constant, but variable. Calculated variable cleat-compressibility constants were found to correlate well with previously published data for other coals. Sorption-induced matrix strain (shrinkage/swelling) was measured on unconstrained samples for different gases: carbon dioxide, methane, and nitrogen. During permeability tests, sorption-induced matrix shrinkage was clearly demonstrated by higher permeability values at lower pore pressures while holding overburden pressure constant; this effect was more pronounced when gases with higher adsorption isotherms such as carbon dioxide were used. Measured permeability data were modeled using three different permeability models that take into account sorption-induced matrix strain. We found that when the measured strain data were applied, all three models poorly matched the measured permeability results. However, by applying an experimentally derived expression to the strain data that accounts for the constraining stress of overburden pressure, pore pressure, coal type, and gas type; two of the models were greatly improved.
Identifying the Timing and Sources of Damage in Gas Storage Wells Using Smart Storage Technology
Authors: Spivey J. P. , Brown K. G. , Sawyer W. K. , Gilmore R. G. 
Published: December 2007

Abstract
Most underground gas storage (UGS) wells suffer loss of deliverability over time, often due to unknown causes. Consequently, deliverability maintenance is one of the primary concerns of UGs operators. The authors believe that a significant aid to identifying the potential causes of damage in UGs wells would be an increased knowledge of when the damage develops. specifically, does the damage develop during injection operations, during withdrawal operations, when a change in flow direction occurs, or continuously? Unfortunately, identifying trends in damage versus time using conventional buildup and falloff tests would be operationally challenging and prohibitively expensive.
An increasing number of UGS operators are using electronic flow measurement (EFM) systems capable of collecting high-frequency (10 to 15 second intervals) pressure and flow rate data at the wellhead. Over the course of normal storage operations, wells will often be shut in for short periods of time. Wellhead EFM data collected during these shut-in periods can be analyzed as buildup or falloff tests. Consequently, UGs operators having wellhead EFM systems often have sufficient buildup and falloff test data to identify trends in damage over time.
Tools have been developed to automatically 1) filter high-frequency EFM data from gas storage wells to identify shut-in periods that can be analyzed as buildup or falloff tests, 2) perform the appropriate pressure transient analysis of the test data so collected, 3) generate semilog and log-log analysis plots, and 4) generate composite graphs of apparent skin s' vs. flow rate and s' vs. date. These tools also allow the user to review and fine-tune the test analyses, and exclude results from any questionable test periods.
The system has been used to analyze data from 20 wells in a major gas storage field for the period December 2003 through May 2005. since wellhead pressure and flowrate data are recorded for each well at 15-second intervals, the system had to be able to process large amounts of data. A total of 357 shut-in periods were identified, 207 of which were analyzable. Three wells had no interpretable tests, while eleven of the wells had 8 or more analyzable tests.
Commingled Production Experiences of Multilayered Gas-Carbonate Reservoir in Saudi Arabia
Authors: Al-Shehri D. A. , Rabaa A. S. , Duenas J. J. , Ramanathan V. 
Published: December 2007

Abstract
Saudi Aramco employed extensive matrix and acid fracturing treatments in the development of Saudi Arabian nonassociated gas carbonate reservoirs. The target reservoir is the Permian Khuff Formation which is the major non-associated gas reservoir in the prominent Ghawar Field, eastern Saudi Arabia. The Khuff reservoir is stratigraphically divided into four correlative zones, namely Khuff-A, B, C, and D in downward sequence. Khuff-B and C are the two major reservoirs with distinctive hydraulic characteristics. Khuff-A and D zones mostly are either discontinuous or have poor to non reservoir quality.
Saudi Aramco is pursuing commingled production selectively as a part of the gas development plan to extend the well's economic life and to meet its growing domestic gas needs.
Since the Khuff-C has better reservoir quality with larger gas reserves, it was completed by itself during the initial period of the field development. Later, the commingled production by adding the Khuff-A and B has become part of the overall strategy to offset the natural decline from Khuff-C and maximize gas production and extend the wells' life.
This paper will review the acid fracturing and stimulation practices employed by Saudi Aramco in the Khuff-Carbonates. The criteria used to select suitable candidates for the commingled production and techniques employed to quantify flow contributions from each individual zone after commingling the production will be reviewed. The production performance, lessons learned, business impact and the way forward will be discussed.
Torque and Drag Modeling for Horizontal Openhole Completions
Authors: Rezvani R. , Techentien B. 
Published: December 2007

Proposal
Since horizontal openhole sections are now being drilled to lengths that exceed 20,000 ft, placement of the completion string (CS) to planned total depth (TD) may not be possible under a proposed drilling plan. During the early years of horizontal-well construction, the hanging weight of the completion string was usually adequate to push it to TD. With the extreme lengths being attempted today, it is important to model the well before attempts are made to run the planned completion to determine 1) whether the strength of the CS can stand the strains (tension, compression, and torque) of installation, and 2) whether there is enough weight in the upper CS to push the lower CS to TD. A software model that uses a wide range of well parameters to enable the operator to predict possible tension loading, compression loading, and torque limits on the CS during installation has long been available. This paper discusses the software and how it can be used in modeling well completion systems.
To calculate the applied forces on the completion string requires the use of a wide range of well parameters and a specialized software program that will allow the prediction of loads and stresses that can be safely applied on the CS during installation. If the modeling process indicates that the CS will not stand the stresses of installation without (1) failing from tensile loading, (2) buckling from the compression load, or (3) failing from rotational torque, a different well plan can be devised or other remedies employed. Charts developed from actual case histories illustrate how the use of torque and drag modeling can be advantageous in all phases of well completion.
Software, Fluids, and Downhole Tools for Successful Sand Cleanouts in Any Wellbore Geometry Using Small Coiled Tubing
Authors: Gilmore T. , Leonard R. , Steinback S. 
Published: December 2007

Abstract
The use of coiled tubing to clean sand from well bores remains one of the industries major areas of activity in well intervention. Recent research work programs have focused on sand transport and cuttings bed modeling with both Newtonian and power law fluids. In large diameter holes, annular velocity is very low, regardless of the coiled tubing's size. Performing well clean outs in these very difficult conditions without the use of expensive or logistically challenging solutions is often impossible. Even with large diameter coiled tubing or concentric tubing strings, the problem of successfully cleaning wells of sand can persist.
This paper will describe a method of cleaning sand from a well, regardless of its geometry or hole size, in a low-pressure environment with small coiled tubing. A description of the philosophy used to clean these wells; the computer modeling utilized; as well as the unique rheological properties of the fluid used; during the clean outs will be made. In addition to fluids and software modeling, a description of the unique jetting tool employed will be made. Case histories will be provided demonstrating sand clean outs performed exactly as predicted by the software modeling in an unprecedented time by utilizing all of these "tool box" items.
The potential to clean any well in one single optimized run in to and out of the well is significant because, as fields mature, more challenging clean outs will continue to be presented. Additionally, clean out economics and the risk of failure will become increasingly important since mature wells and fields are by their very nature unable to bare excessive intervention costs. The importance of using software, down hole tools and fluids for cleaning sand from these wells will be demonstrated. The application of all of these techniques simultaneously offers the opportunity to clean all wells economically with existing standard coiled tubing units.
Medusa Project: Integrated Planning for Successful Deepwater Gulf of Mexico Completions
Authors: Soter K. , Malbrough J. , Mayfield D. , Holland J. 
Published: December 2007

Abstract
The following will outline the Medusa Field development and completion design process highlighting an integrated approach between engineering disciplines and service providers to exploit the enormous amount of exploratory well data. The Medusa development, located in Mississippi Canyon blocks 538 and 582 offshore Louisiana, is a truss SPAR allowing for both dry tree production and multiple subsea tiebacks. A field overview from a geological and reservoir perspective, along with the drilling and field development considerations, will be summarized.
The initial phase of the Medusa truss SPAR development includes ten compaction-tolerant FracPac completions in six dry-tree wellbores. Phase II wells included the drilling of two subsea tiebacks. One was drilled and deemed uneconomic while the second, Medusa North, was completed and tied back in early 2005.
The paper will show how the information gathered during the drilling phase was applied to the completion design to ensure long-lasting, reliable and profitable wells.
The Viability of Single-Trip Sand-Control Completions in Deep Water—A Case History
Authors: Cole B. , Franklin B. M. , Cody R. , Littleton R. 
Published: December 2007

Abstract
Escalating development costs and increasing deepwater activity emphasize the need for reducing well completion costs dramatically. The evolution of single trip systems in the Gulf of Mexico Shelf provides proven technology to complete marginal properties in deepwater.
Workstring trips on deepwater completions are the single most expensive operation; therefore minimizing trips can significantly reduce operational costs. Today, wells are being drilled deeper and therefore the impact of reducing the number of trips is significant. Single trip systems executed successfully in today's deeper environments can offer considerable savings. Realized project savings depends on the type infrastructure in place, i.e. Semi-Submersible, Drillship, Spar, TLP. Single Trip systems offer a viable option to reduce costs, however candidate selection and additional engineering considerations are associated with these systems.
The progression of single trip systems to multi zone completions systems is examined along with the inherent advantages they present. Based on the completion architecture and rig infrastructure in place tangible savings in excess of half a million dollars can be realized. Installation of single trip systems, a deepwater completion performed from a drill ship, and the cost analysis for the feasibility of this application is presented.
External Casing Perforating Provides Optimal Treatment Coverage in Horizontal Pay
Authors: Rodgerson J. L. , Ruegamer M. L. , Snider P. M. 
Published: December 2007

Abstract
Multi-stage treatments in horizontal wells have become the "Holy Grail" of the service industry. Combining horizontal drilling technology and multiple stimulation stages along the length of the borehole has allowed operators to develop many new reservoirs around the world. The Barnett Shale formation in Texas has received the most recent notoriety. Many techniques have been offered to optimize treatment coverage throughout horizontal intervals including limited entry, sliding sleeve; barefoot open-hole and coiled tubing (CT) completions. These techniques can be very efficient and provide good coverage in lateral completions, but time and again this is accomplished with a sacrifice of net pay. Some of these techniques can be somewhat time-consuming and expose the operator to undesirable risk.
A relatively new multi-stage treatment process optimizes perforation and treatment designs in either vertical or horizontal completions. The technique, known as "external casing perforating," allows the operator to perforate and isolate individual zones with as little as 15 minutes between treatment stages. As many as 17 discrete intervals have been treated within a 24-hour period in a vertical completion. In most cases elapsed time to first sales has been dramatically reduced.1 Production from these wells has been brought online quickly in a single rig-less operation without damaging and time-consuming shut-ins.
The paper will explain the external casing perforation technique in horizontal applications and compare it to other methods available in the industry. A major portion of the paper will focus on the field installations to-date and the operational methodologies employed to ensure success. Additionally this paper will describe benefits such as zonal isolation and ease-of-use and provide comparative success metrics for both conventional and horizontal applications.