bluuebunny/crossref_metadata_2025_split huggingface dataset:
Scale Removal by Milling and Jetting With Coiled Tubing
Authors: Enerstvedt Eirik , Boge Henning 
Published: December 2007

Abstract
This paper describes scale cleanout jobs performed with Coiled Tubing offshore in the North Sea on 7 well for Phillips Petroleum Company Norway
The cleanout has been done by first perform milling runs with a standard PDM motor, then the completions jewelry has been cleaned by use of a jetting nozzle head with a metal to metal seal motor as a drive mechanism.
In some of the wells multi-finger caliper has been run both before and after the cleanout. The caliper has confirmed a clean well. In others drift run has been performed and gas lift valves has successfully been replaced. An increased oil production from the wells is also achieved
Both Weatherford CTD PDM motors and the metal to metal seal Weatherford MacDrill motor together with the Weatherford MacJet head has proved to be strong and reliable tools for this kind of operations.
Coiled Tubing Innovation Advances New Completion Concept
Authors: Morrison Dan W. , Brake Sean C. , Martch Eddy 
Published: December 2007

Abstract
This case-history paper focuses on the evolution of a novel completion concept. The concept resulted from improvements in through-tubing vent-screen technology and the invention of a wireless casing collar locator (CCL) for coiled tubing (CT) operations. This completion method provides the following: reduced completion costsimproved completion efficiencyextended completion lifereduced mechanical riskimproved reserve recovery rate
The invention of the wireless CT CCL was a key development that advanced this completion technique.
A new surface-modification agent (SMA) is at the core of this completion process. The SMA is a water- and oil-insoluble, resinous liquid additive that does not harden or cure under reservoir conditions. This additive is applied to proppant during the sand-control portion of the completion process to increase the cohesive forces between the proppant grains. The SMA provides the following advantages: It can help increase pack permeability and porosity by up to 30%.It helps control fines migration.It decreases mechanical risk by helping stabilize the annular pack.
Tests have shown that using of SMA increases the critical flow velocity of the annular pack. It (1) allows the well to produce at higher rates without producing the sand from the annulus or (2) allows the operator to shorten the completion blank length at a given production flow rate, and (3) allows the length of the completion assembly to be reduced, providing flexibility that allows the completion method to be used on wells with closely stacked pay zones.
Before the development of CT CCL, operators had to use CT rigs with an electric line in the tubing to power downhole tools with perforating collar locators or gamma ray (GR) perforators. This system could triple or quadruple job costs. Wireless CCL allows accurate depth measurements with CT, making it possible to run guns and packers on CT with an existing GR CCL log as a reference. The CT CCL eliminates the need for e-line and reduces the completion time and daily spread cost. When the space limitations and the time required for repositioning the equipment for different phases of the operation are considered, the time associated with spotting equipment in offshore operations can be substantial. The CT CCL reduces completion time.
The following case histories describe economically successful jobs performed with these integrated services.
New Biopolymer for Coiled Tubing Applications
Authors: Navarrete R. C. , Shah S. N. 
Published: December 2007

Abstract
Xanthan gum has been used extensively as a viscosifier in coiled tubing due to its unique friction reduction properties. In this paper we describe the friction pressure properties of a new, previously introduced, biopolymer for use in coiled tubing applications. The name of the polymer is diutan. Diutan yields higher low shear rate viscosities at lower polymer concentrations than xanthan gum due to its higher molecular weight. Diutan is more shear thinning that xanthan gum. As a consequence, the high shear rate viscosities of diutan are lower than those of xanthan gum at comparable low shear rate viscosities.
Large scale friction pressure tests in coiled and straight tubing were conducted to observe if the lower high shear rate viscosities of diutan translated into lower friction pressures. The results of these tests showed that both xanthan and diutan exhibited significant drag reduction. However, the percentage drag reductions of diutan were larger than those of xanthan gum.
Application and Design of Unbalanced-Drilling With Formation Fluid Injection
Authors: Zhou Lei , Zhou Kaiji 
Published: December 2007

Abstract
In the broad sense, unbalanced-drilling is not only an effective technology of exploiting low pressure and low permeability formation and exhausted formation, but also a drilling and completion technique for finding and exploiting formations which are different pressure systems. Unbalanced-drilling pressure difference can be obtained by use of single-phase fluid, aerated fluid, tiny glass bead, and tiny plastic bead. If unbalanced-drilling pressure difference is obtained by different ways, drilling cost will be much variable. Under allowable formation pressure, single-phase and low-density fluid was injected from surface. When it was circulated in the annular space, it can stimulate formation fluid into annular space so that we can obtain the designed unbalanced-drilling pressure difference, working-on process, and theory of annular pressure system. How to select single-phase fluid injected from surface, and to obtain of initial unbalanced-drilling pressure difference, calculation and control technique of characteristic factor of annular multiphase fluid dynamics, control and calculation of injection quantity of formation fluid, control technique of unbalanced-drilling casing pressure and standpipe pressure, were discussed and analyzed in this study in detail. This technology has been applied to Northern China Oil Field successfully.
Sources and Uses of Non-Propriety Economic Data: What Every Evaluation Engineer Should Know
Authors: Miller Richard J. 
Published: December 2007

Abstract
This paper builds upon previously reported prior work using data from fair market value sales of oil and gas properties and from capital market analysis to (a) examine the relationships among certain market valuation parameters and the ways in which those relationships may correctly or incorrectly influence evaluation practice and decision making and (b) to summarize and compare the results obtained from three recognized studies of evaluation data.
The examination of relationships portion will focus on two specific areas; (1) the relation of the discount rate to the rate of price and/or cost escalation used in an evaluation and (2) the relation of the discount rate to the performance of selected capital markets for debt and equity, and inflation. This part of the work examines some of the many questions and issues which are often raised regarding the use of market data for valuing properties and also regarding the selection of appropriate evaluation parameters.
The summary and comparison will contrast the construction, data analysis methods, and results obtained by three commonly used studies: (a) the SPEE Annual Parameter Survey, (b) the annual study done by the Texas Comptroller of Public Accounts for the appraisal of oil and gas properties, and (c) the Western States Petroleum Association annual study of oil and gas property sales and oil industry cost-of-capital. These studies are often cited in evaluation reports and in publication which discuss evaluation procedures. The three studies are found to have significant similarities of objective and results while starting from differing data sources and using different methods to achieve the reported results. The paper will show that the three studies, each with a 10-15 year history can be used together to define a continuum of evaluation information which provides a source of discount rate, price/cost escalation, and risk consideration data for knowledgeable persons involved in valuing oil and gas properties.
High Rate Formation-Pack a Technique for Sand/Water-Control
Authors: Sachdeva Surinder S. , Johari Anil , Patel Hasmukhbhai R. 
Published: December 2007

Abstract
The oil industry continues to face the problem of sand production /movement along with the oil/gas due to migration of fine sand. The most common method for sand control is mechanical method of sand-control by gravel packing with installing a assembly in the well, before commencement of oil/gas production. The gravel-pack results in slightly lesser productivity due to pressure-drop across the pack / liner. This also sometimes results in complicated fishing in case of deep / inclined wells. An innovative idea of packing the formation with suitable gravel at high rate has been tried in-all 30 wells to arrest the movement of sand. It has been termed as "High Rate Formation-Pack".
Correction of the Non-Darcy Coefficient for Completion Effects: Impact on the Prediction of Tangguh LNG Gas Well Deliverability
Authors: Zulfikri Zulfikri , Abdassah Doddy , Seno Adjie Bugi Umar 
Published: December 2007

Abstract
The Tangguh LNG gas fields are situated in the Berau Bay, Irian Jaya, Indonesia. An extensive exploration and appraisal program was performed from1994 to 1998 which resulted in the discovery of 14.4 TCF of proved gas reserveswith substantial upside reserve potential. The fields are currently at thedevelopment planning stage in support of the Tangguh LNG project, Indonesia'sthird major LNG center.
The objective of this work was to obtain a more accurate skin and non-Darcycoefficient (D) from exploration and appraisal well tests by accounting forcompletion effects. The impact of corrected D coefficient on welldeliverability reduced the number of forecasted development wells.
In Tangguh pressure transient analyses, skin and D coefficient from welltests were first calculated based on pressure data from gauge depth. Most ofthe gauges were placed in gauge carriers integral to the test string andanywhere from 125 to 300 feet above the mid-point of producing interval.Because the pressure drop in the completion from the perforations to the gaugeappears as additional skin, the deliverability of the formation could beunderestimated if this effect were not considered in the analysis.
After the pressure drop in the completion was correctly accounted for, thenon-Darcy coefficient decreased in all wells. The D coefficient correction wasparticularly significant in high transmissibility reservoirs and agreed withtheoretical D coefficient calculations. This increased the predicted gas welldeliverability.
Rotary Steerable Drilling Fluid
Authors: Bland R. G. , Reeve J. W. , McNair G. A. 
Published: December 2007

AbstractNew mud chemistry is shown to improve the efficiency of directional drilling with a rotary steerable drilling system. Full-scale (8½-in. bit) drilling results using a rotary steerable drilling system drilling to horizontal at an experimental test site and an application in the Huizhou 21-1 field, offshore Hong Kong in the South China Sea are presented documenting the effectiveness of this technology.
Evaluation of Skin for High Deliverability Gas Well Tests
Authors: Elshahawi H. , Gad K. 
Published: December 2007

Abstract
In general, any restriction to flow that causes a distortion of the flow lines from being perfectly normal to the borehole direction would result in positive skin. As a result, the skin factor computed from well testing is a widely used indicator of the overall flow efficiency of a given well. This is theoretically valid, but often, a high positive skin indicated from a well test is assumed synonymous with a large extent of near-wellbore formation damage and is, therefore, frequently used as a criterion to perform stimulation treatment meant to enhance the well productivity. This latter practice is generally not valid since the skin factor computed from a well test is, in reality, a composite variable that is not merely a function of near-wellbore damage. This skin factor is also a function of parameters such as perforation geometry, well deviation, partial completion, and other phase and rate dependent effects. Therefore, the skin computed from a well test must first be broken down into its constituent components in order to determine the "true" near-wellbore skin. Moreover, the skin and permeability values computed from a well test are so intimately related that an error in one directly impacts the other. Typically, additional input data would also need to be integrated in any given permeability-skin model in order to reduce the computational uncertainty. Only after proper modeling, can an appropriate stimulation treatment be selected. This is particularly important for high-deliverability gas wells, for which the formation damage-related skin often makes up only a small portion of the total well test-measured skin.
This paper outlines a methodology that can be used to compute the various skin components as well as representative values of the average formation permeability from a well test. Several examples from gas wells are presented to demonstrate the utility of this methodology.
Production Enhancement in the Belayim Fields: Case Histories
Authors: Elshahawi H. , Siso S. , Samir M. , Safwat M. 
Published: December 2007

Abstract
Inadequate productivity of perforated wells has been a major concern since the introduction of cased completions. Petrobel company, operating in the Belayim fields of Sinai, Egypt, and responding to an unpredictably fast decline in field production, launched an initiative in 1996 to identify the under-performing perforated wells in order to plan remedial actions. Since the vast majority of the wells were under artificial lift, this involved the integration of data from various sources. The study revealed that the majority of wells in the field were in fact suffering from excessive damage. Wells were then categorized based on the value of their completion factors (the ratio of actual to theoretical productivity indices), and the potential sources of damage were identified for each category. This was accomplished using techniques such as nodal analysis and skin modeling.
One of the most successful techniques used to cure the damage was the re-perforation of the damaged wells with deep-penetrating perforating charges. Until the use of this technique, and even with attempted improvements in other operating parameters, field performance had continued to fall short of theoretically predicted results. This paper highlights the origin and development of formation damage in the Belayim fields, and how this damage was attributed to different damage mechanisms using a novel combination of nodal and damage analysis techniques. It also presents some cases of dramatic productivity enhancement due to the use of these techniques and the introduction of deep penetrating perforating.
Six Sigma Tools Applied in Automatic Well Testing-Reducing Response Time to ’No Fluid Detected Wells’
Authors: Sihombing Santun , Purnomo Agus , Brahmantyo Akson 
Published: December 2007

Abstract
The Duri oil Field has 3,000 active wells divided into 9 (nine) areas. To measure the volume of oil and water produced, each well is tested approximately twice a month. When an NFD (no fluid detected) condition occurs during the test, the well is not performing properly and should be checked to see what requires repair.
Cycle time to put the well back to production depends on: response time to NFD wells, number of NFD wells found that day, the type of repair required, and the resources available to make the repair. Without intervention, the NFD wells automatically are put back into retest by the programming logic. Historical data from Area-4 in 1999 shows that wells were off production an average of 405 days/month due to NFD status. With a median production of 34 BOPD / well, 450 BOPD was not being produced. At a crude price of 12.5 US $ / barrel the total lost opportunity cost is 2 MM US $/ year.
Starting in late February 2000, the project team began deployment of Six Sigma tools, with the result that the response time was reduced to only 300 days in March and then farther reduced to 140 days in April and May. The number of individual NFD wells was reduced from a 1999 average of 69 wells to 54 wells in March and 25 wells in April and May. The effort resulted in a production increase which equates to an annualized opportunity gain of 1.0 MM US $/ year. The background, objectives, and results of the Area-4 respond time to NFD wells improvement program are presented in the report.
Some Predictions of Possible Unconventional Hydrocarbons Availability Until 2100
Authors: Kawata Yuko , Fujita Kazuo 
Published: December 2007

Abstract
This paper presents several trial calculations on supply and demand forecast of the unconventional hydrocarbons (UHC) under the control of CO2 emission using the Ultra-Long Term Supply/Demand Balance Model1. We performed five cases of variation on the basis of BAU (bussiness as usual) case. As a result, the substantial production of UHC would begin around the year of 2030, and the production cost should jump up to about 1.5 ~ 2 times of the present conventional gas cost toward 2100. Most of the under-developing countries will be fully developed to increase their energy consumption. Thus, transfer of technologies to under-developing countries shall become important and it may be not enough for reducing CO2 emission to expand natural gas consumption only. Therefore, a combination of various measures, in another words, best-mix formula of primary energy supply is essential. Especially, the promotion of energy conservation and the utilization of renewable energies would be more effective measure for CO2 reduction as well as controlling the UHC production cost.
Deepwater Production with Surface Trees: Trends in Facilities and Risers
Authors: Ronalds B. F. , Lim E. F. H. 
Published: December 2007

Abstract
As oil and gas production has moved into deeper water, and with the common requirement for platform drilling and/or frequent well intervention, new solutions have been developed to support rigid risers and surface trees. The four types of dry completion unit employed to date – jackets, compliant towers, TLPs and spars - are described and compared, along with their advantages and current limits of applicability. A database of deepwater production platforms is included.
Platform optimisation cannot be performed in isolation from riser considerations, as the requirements of the risers are intimately related to the operating characteristics of the production facility. This interrelationship, and resulting trends in both platform concepts and production riser configuration, is explored. A key issue is the tendency for the risers to displace vertically relative to the facility, which becomes very significant for softly-moored hulls in ultra-deepwater. This displacement may be accommodated by modifying the riser shape, make-up and method of support.
Gas Slippage in Two-Phase Flow and the Effect of Temperature
Authors: Li Kewen , Horne Roland N. 
Published: December 2007

Abstract
Gas slippage in single-phase gas flow (Klinkenberg Effect) has been investigated extensively. Few papers, however, have been published on the gas slippage in gas-liquid two-phase flow. The gas relative permeabilities at water saturations close to the residual value have been found to be significantly greater than one in both nitrogen-water and steam-water flow through rocks. These values became less than one after the calculation was calibrated by taking the two-phase gas slip effect into consideration. The gas relative permeabilities have been measured at different mean pore pressures and the values of two-phase gas slip factor have been computed at different water saturations. The effects of temperature on both nitrogen and steam slip factors have also been studied and compared. These data have then been used to conduct a calibration in order to obtain intrinsic gas relative permeabilities that do not vary with the test pressures. It has been found from the present work that neglecting the two-phase gas slip effect may overestimate gas relative permeabilities. It is the intrinsic gas relative permeabilities instead of those measured at low test pressure that should be utilized in numerical simulation or other reservoir engineering calculation.
Deployment and Development of Computer-Based Learning for the Upstream Petroleum Industry
Authors: Sargent B. C. , Bihn G. C. , Ford J. T. 
Published: December 2007

Abstract
A unique training initiative utilizing computer-based material and a learning management system, designed to fill experience gaps of professional staff in the upstream petroleum industry, has been developed. This paper introduces and provides a basis for the initiative, and the benefits of using computer-based learning (CBL) in such an initiative.
The focus of the paper is on deployment and development of CBL material, and in particular: The development of training programs using CBLExisting CBL material and the deployment thereofCurrent/planned CBL development and the future of the program
In view of the worldwide shortage of E&P professionals, existing high-quality E&P computer-based training material and an off-the-shelf learning management system (LMS) are being used to expedite deployment of the program. As the deployment of existing material proceeds, the development of new CBL courses varying in breadth, depth and delivery platform is a key element of the initiative and is already underway. In the future both academic degree programs and professionally certified programs with varying amounts of CBL material will be available.
The potential benefits of training programs utilizing CBL are significant. First, the experience level of professional staff can be improved by on-demand, just-in-time learning. Second, the need for instructor-led training (ILT) can be minimized. Lastly, coupled with traditional on-the-job and ILT, innovative CBL material can cost-effectively accelerate and enhance the learning process.