bluuebunny/crossref_metadata_2025_split huggingface dataset:
Evaluating the Economics of Gas Storage Well Deliverability Enhancement
Authors: Reeves S. R. , Beckman K. L. 
Published: December 2007

Abstract
Maintaining and enhancing the deliverability of gas storage wells has become increasingly critical for gas storage companies to remain competitive in this newly deregulated environment in the U.S. Unfortunately, standard methods to adequately evaluate the economic results of deliverability enhancement activities, and hence optimize them, are currently unavailable. This paper presents two new methods that begin to address the unique economic evaluation requirements of gas storage well deliverability enhancement. The first method is for application when the objective is to minimize the cost of maintaining deliverability, and the second when the objective is to maximize the economic value of a storage asset by upgrading it to shorter-term, higher-value service. Results from this study indicate that new and novel storage well stimulation methods, such as tip-screenout fracturing and fracturing with liquid CO2 and proppant, can provide substantial improvements in the economics of deliverability enhancement over more traditionally used methods. In addition, economic incentives may exist in some cases to upgrade current baseload facilities to shorter-term, higher-value service, although other, non-financial conditions still present barriers to activity in this direction. While the new methods presented in this paper represent an important improvement over current economic evaluation approaches, further advancements in this area are still needed.
Four Criteria for Selecting International Petroleum E&P Investment Opportunities
Authors: Wang B. , Litvak B. L. , Kokolis G. P. , Rapp W. J. 
Published: December 2007

Abstract
This paper presents four criteria suggested for selecting international petroleum E&P investment opportunities. It will be demonstrated how these criteria facilitate economic evaluation of E&P new business development opportunities. The two types of opportunities for which the utility of these criteria will be demonstrated, are exploration and discovered reserve opportunities, which require development, in various different fiscal regimes.
The four criteria presented are Expected Net Present Value (ENV), Risked Present Value Ratio (RPVR), Value-to-Buy-in Ratio (VBR) and Earnings per Gross-Working-Interest Barrel (E/GwiB). Earnings per Net-Working-Interest Barrel (E/NwiB) is not recommended for the screening criterion because of distortions caused by the fact that NWI Reserve calculations can be quite different for different fiscal regimes.
Three XY plots are suggested for use: (1) ENV vs. Risked Net Cost, with a slope of RPVR, (2) ENV vs. Buy-in Cost with a slope of VBR, and (3) Risked Earnings vs. Risked GWI Reserves with a slope of E/GwiB. Some examples will be shown how these plots can be used to evaluate opportunities for investment
A GWI-Barrel-Split method is also demonstrated that facilitates comparison of investment opportunities. This method splits the project BOE price into four per GwiB ratios: F&D/B, Opex/B, Government Take/B and Earnings/B. A plot showing the comparisons of the five ratios provides comprehensive information of project economics.
Waterflood Strategy, Challenges and Innovations
Authors: Kenawy F. A. , Bibars O. A. , Hanafy H. H. , Rezk A. S. 
Published: December 2007

Abstract
More than twenty four years ago, Gupco (Gulf of Suez Petroleum Company) initiated the first waterflood project in Egypt for the giant El Morgan oil field. With continuing waterflooding experience, Gupco has applied this improved recovery method for other fields. Currently Gupco operates 14 different waterflood reservoirs. These reservoirs have produced a cumulative oil representing 40% of their original oil-in-place. On average, the projected waterflood recovery factor is 54% of OOIP. Due to non-uniform lithology and non-uniform pattern of existing well locations in most reservoirs, peripheral waterflood was found to be the most suitable and economic waterflood pattern at project startup. Peripheral waterflooding has the advantage that it minimizes the number of injection wells by converting the watered-out producers. As the Gupco reservoirs become more mature, the line-drive pattern (peripheral + up-dip injection) was found to be more effective. Since most of the Gupco's reservoirs are currently in the mature stage, good managing and close monitoring for each waterflood project is extremely important. This paper presents Gupco strategy in managing the different waterflood projects to maximize both the oil production rate and oil recovery in optimum manners. This is being achieved through several common and familiar waterflood issues including: a) pressure maintenance, b) in-fill drilling, c) zonal injection improvement, d) injection pattern modification, e) injection below formation parting pressure, f) workovers for production and injection wells, g) continuous data collection, and h) water quality monitoring. The paper also shows how Gupco is addressing the waterflood side effects of scale buildup, reservoir souring and facilities corrosion. In addition, the paper discusses some of the innovative techniques that Gupco has used to maximize waterflood recovery and enable waterflooding of marginal fields. Examples for these techniques are gas-cap water barrier injection, heavy oil waterflooding, coiled-tube water injection lines, slim-tube dual completions, and satellite waterflooding for pilot and marginal fields waterflooding.
Design and Analysis of Interference Tests
Authors: Lescarboura J.A. , Walther H.C. , Wilson P.L. 
Published: December 2007

Abstract
Interference tests can show when wells are in the same reservoir and give areal average values for formation transmissibility, kh/ µ, and formation storage, Î¦hct. When combined with single-well buildup/fall-off tests, interference tests can also identify various reservoir heterogeneities. Even though straightforward interference tests a Fe simpler to run than pulse tests, they have been neglected in recent years due to misconceptions about test-time requirements. While characterizing reservoirs for tertiary recovery pilots, we have developed methods to design, run, and analyze interference tests. These techniques are covered in detail. Special problems such as wellbore storage effects, reservoir layering, barrier effects, etc., are discussed. The main conclusions are that interference tests can be performed with greater ease and in about one-third the time of equivalent pulse tests when the same gauges are used. Accuracy of results is comparable.

Introduction
For interference testing, a rate change in a source well causes a reservoir pressure transient that is measured in a shut-in observation well or wells. When the rate change is cyclic, the test is called a pulse test. Interference tests can show if wells are in the same reservoir and give areal average values for the formation transmissibility, kh/ µ, and formation storage, Î¦hct. Combined with conventional single-well tests, interference tests can also identify reservoir layering, determine fracture orientation, and locate barriers. While characterizing reservoirs for tertiary recovery pilots, we have seen examples of all these cases. In doing this work, methods were developed to design, run, and analyze interference tests, and these techniques are the subject of this paper.
Cost Effective Design of Corrosion Inhibitor Squeeze Treatments for Water Supply Wells
Authors: Kokal Sunil , Raju Kris , Biedermann Allen 
Published: December 2007

Abstract
Water for pressure maintenance in oil producing reservoirs is often obtained from wells that are drilled in water aquifers. Aquifer brine is corrosive and leads to the corrosion of well tubing, manifolds and water injection system. Downhole squeeze treatments with corrosion inhibitors provide an effective means of controlling the corrosion problem in supply wells and injection system. Filming amine type corrosion inhibitors are "squeezed" into the aquifer and the chemical returned with the produced water provides the necessary protection.
This paper presents an analysis and design study of corrosion inhibitor squeeze treatments for aquifer water supply wells. Laboratory and field data are presented for optimizing chemical usage and squeeze strategies. Corefloods conducted at reservoir conditions show that adsorption/desorption is the dominant mechanism of corrosion inhibitor retention and release from the formation. Squeeze treatments were simulated in the laboratory to determine the effect of important variables on squeeze life. These variables included the amount and concentration of inhibitor, volume of formation to contact, amount of overflush and the shut-in time. Laboratory testing and field trials have insured corrosion control at reduced operational costs. This has been attributed to the teamwork between laboratory personnel and operation engineers. Recommendations are made for optimizing future squeeze treatments.
Decision Tree Analysis and Risk Modeling To Appraise Investments on Major Oil Field Projects
Authors: Gatta S. R. 
Published: December 2007

Abstract
A deterministic approach is customarily employed in planning and budgeting process. More often than not, the experience shows that the targets (e.g. capital expenditure and completion time) are not achieved. A better view, however, of all the underlying uncertain parameters would have a significant effect on the decision makers' success as risk takers and ultimately therefore on the corporate profits.
The paper presents decision theoretic approach applied to appraise investments on a major oilfield project. The occurrence of different outcomes taking place over the planning horizon is a function of the (i) decisions preceding the event and (ii) chance phenomena concerning the individual physical and economic parameters. A decision tree is diagrammed to satisfy the feasible alternatives whether caused by options deliberately exercised or events naturally occurring. Thus, there is scope to test economic or other consequences before committing resources.
Risk modeling to evaluate the uncertainties in the resource availability, success/failure rates, capital constraints, oil market and the general economic environment is a complimentary part of the decision model incorporating the decision tree. Monte Carlo simulation technique is applied in the implementation of the decision model.
With proper definition of independent stochastic variables by their probability distribution functions, it has been possible to derive the risk evaluated economic yardsticks for each set of decision parameters thereby enabling the decision maker choose the optimum course of action keeping the financial and market risks in perspective. The real life example reported in the paper illustrates the major aspects of the recommended approach: (a) updating the decision tree and the model parameters based on the additional information gained during the actual implementation of the decision model, and (b) aiding the management decision making process to evaluate the consequences of exercising different options before committing the resources.
Bubble Point Pressure and Oil Formation Volume Factor Correlations
Authors: Al-Shammasi A. A. 
Published: December 2007

Abstract
This paper evaluates published correlations and neural network models for bubble point pressure and oil formation volume factor for accuracy and flexibility to represent hydrocarbon mixtures from different geographical locations worldwide. The study presents a new correlation for bubble point pressure based on global data with improvement in performance over published correlations. It also presents new neural network models and compares their performance to numerical correlations.
The evaluation examines the performance of correlations with original published coefficients and with coefficients calculated based on global data, data from a specific geographical locations, and data for a limited oil gravity range. The evaluation of each coefficient class includes geographical and oil gravity grouping analysis. The results show that the classification of correlation models as most accurate for a specific geographical area is invalid to be used for these two fluid properties. Statistical and trend performance analysis shows that some of the correlations are violating the physical behavior of hydrocarbon fluid properties. Published neural network models are missing major model parameters to reproduce. New developed models performed better, but suffer from stability and trend problems.
A New Stream-Tube Model for Waterflooding Performance in 5-Spot Patterns
Authors: El-Khatib Noaman A. F. 
Published: December 2007

Abstract
A new mathematical model is developed for waterflooding performance calculation in 5-spot pattern reservoirs using stream tubes. The method is based on estimating the location of the displacement front in any stream tubes relative to the location in any other tube at the same real time. Areal sweep efficiency, fractional oil recovery, fractional water flow and the injectivity ratio are calculated as functions of thetotal injected P.V. of the displacing fluid. The effect of mobility ratio on the performance is investigated. Comparison is also made between the performance obtained assuming piston-like displacement and that assuming Buckley-Leverett frontal advance theory.
Start-up of Peripheral Water Injection
Authors: Davis D. W. , Habib H. H. 
Published: December 2007

Abstract
Peripheral water injection began into the pressure depleted Wafra Ratawi Oolite reservoir during July, 1998. Sixteen water injection wells are currently being utilized to inject 44,000 BWPD using low pressure charge pumps from the hydrocyclone and filtration skid. Design rate under high pressure injection is 200,000 BWPD using twenty-six injection wells. The water injection facility design, injector well location criteria, and reservoir performance data obtained from injectivity tests and spinner surveys are documented. Initial comparison between reservoir simulator predicted water injection rates versus actual injection rates provide some useful insight into the future success of the project. Recommendations regarding future operation of the injection facility and injection wells are highlighted.
Vertical Gas-Oil Displacements in Low Permeability Long Core at Different Rates and Pressure below MMP
Authors: Soroush H. , Saidi A. M. 
Published: December 2007

Abstract
The aims of this laboratory experiment were: 1-To show the potential of a high oil recovery from one md permeability reservoirs by lean gas injection below MMP. 2-To be able to evaluate the dynamic behavior of immiscible displacements, and solution gas drive processes using commercial compositional simulation models. 3-To demonstrate that the sharp increase in recovery from a pressure of about 3500psi in the VGD displacement, is partly due to the thinning of the adsorbed film and thus the shrinkage of pendular rings as well as the possibility that the displacing phase starts wetting the rock surface.
The MMP of a reservoir oil with a bubble point pressure of 4200psi and a lean injection gas was found to be 4400-4500psi at a temperature of 237°F, using the slim tube method with a recovery of close to 92%. Experiments were performed on a 159.5cm long reservoir rock sample with an average permeability of one md and 16.5% porosity, with the same oil and gas, at an injection rate of 1 to 10 cc/hour with a recovery of respectively from about 74% to 62%. The effluent GOR and gas compositions were measured during the experiments. An experiment with 10% connate water saturation at a gas injection rate of 5cc/hour gave a similar oil recovery to that without connate water. These injection rates are several times larger than the gravity stable rate for this low permeability sample. This means that in a low permeability conventional reservoirs, gas injection at a higher rate than the gravity stable rate could still produce over 60% of the oil in place. In case of fractured reservoirs with a small threshold height, the recovery factor would be closer to the upper values since the displacement takes place under gravity stable rate.
A natural depletion run at 60psi pressure drop per hour was also made, with oil recovery of respectively 22 and 25.6% at 1000psi and atmospheric final pressures.
The analytical methods of calculating gravity drainage performance discussed in literature are critically reviewed. are Comments were made on the approaches, boundary conditions, the behavior of one phase and two-phase flow regimes, required conditions to form dimensionless groups, the effect of threshold height on production rate, the use of threshold pressure in calculating the pressure gradient in a block, etc. in solving the gravity drainage performance.
Barik 3D reshoot: tailormade acquisition for multiple objectives
Authors: Hoetz H. G. , Duyndam B. P. M. 
Published: December 2007

Abstract
The Barik anticline, situated in the southern part of the Ghaba saltbasin (Central Oman) harbours hydrocarbons at several levels. A large gas-condensate accumulation at a depth of 4.2 km lies beneath a mature oilfield at 2.5 km. The former is currently being developed in conjunction with the nearby Saih Rawl field for Oman's LNG project.
To improve the structural definition of the Barik field, a new seismic survey was designed to image these multiple levels. Advantage was taken of a recently introduced orthogonal acquisition geometry that allows 3D surveys for deep targets to be acquired more cost effectively. Proper imaging of the shallow oil target however, required local adjustment to the basic orthogonal geometry by adding infill lines. Additionally, the objective of firming up several exploration leads around the adjacent Al Ghubar saltdome, was also included in the design.
The tailor-made 900 km2 survey was acquired in the first half of 1998 with processing taking most of the second half. Data quality, in particular for the deeper targets, is superior compared to the previous survey. The improved structural interpretation already allowed to pick gas development wells in areas which were poorly imaged on previous data.
Creating a Positive HSE Culture in Order to Implement Operational Integrity Assurance System
Authors: Kerrigan John 
Published: December 2007

Abstract
BPAmoco have a system called Operations Integrity Assurance System (OIAS) that operations must fulfill to comply and deliver BPAmoco's Health Safety and Environmental Policy. OIAS consists of thirteen elements and associated "management expectations" and provides a "framework" within the Health Safety and Environmental Management System (HSEMS) for Policy delivery.
Audit is one of the tools used to assess the level of compliance and to improve, but more particularly BPAmoco are addressing behavioral issues within its HSEMS and audit program in order to create a more positive Health Safety and Environmental (HSE) culture within the organization.
Traditionally HSE Audits have tended to focus on equipment and procedural deficiencies without really addressing people issues adequately. It should be remembered that probably 98% of accidents are caused by people, and hence managers should do less inspection (hardware) and more systematic auditing through dialogue and listening to people in the workplace. This will lead to improved HSE culture and more effective implementation of the HSEMS and more importantly lead to improved HSE performance.
This paper describes BP's Operational Integrity Assurance System (OIAS) and the behavioral audit tool currently being used to improve the HSE culture and OIAS implementation. BPAmoco see future improvement in HSE performance linked to an overall safety program of which behavior modification in the workplace is crucial. The paper also describes how this systematic auditing approach can be used not just at operational work-sites but in project design offices.
Performance of Al Rayyan Field under Aquifer Pressure Support
Authors: Burno R. T. , Tucker R. D. , Noman R. , Abdulla I. A. 
Published: December 2007

Abstract
This paper will present a case study of production performance and analysis of A1 Rayyan, an offshore carbonate oil field, producing under strong natural aquifer pressure support. The field currently produces from six horizontal wells in the Arab A and C formations located in offshore Qatar. This field has been on production for two years as part of an early production & appraisal phase. Production is through the use of coiled tubing conveyed ESP, where the power cables are inside the coiled tubing. This protects the power cables from corrosive fluids and is known to be the world's first use of such a technique. Utilization of this ESP technology will also be briefly discussed in this paper.
During this early production period a number of pressure surveys were carried out to monitor performance of the two reservoirs. The paper will discuss examples of some typical pressure buildups analyzed on the horizontal wells producing at high water cuts and under strong natural aquifer support. Average pressure calculated from the buildup surveys indicate strong pressure support in the Arab C where reservoir pressure has remained close to the initial conditions even after two years of production. Such strong pressure support in the Arab formation has rarely been reported in this area before, and therefore provides an interesting case history. In the Arab A reservoir however, pressure has declined and water injection is currently under consideration. Material balance was used to estimate oil in place, aquifer size and investigate the sensitivity of aquifer parameters. Simulation studies have also been carried out to investigate pressure performance of the reservoirs and associated aquifers, bur are not reported in this paper.
An interference test carried out with one source and two observation wells is also discussed. Due to the high permeability, pressure buildup tests have shown distinct recognizable early and late time radial and linear flow regimes detectable in the log-log plots. Difficulty of conducting buildup surveys with ESP inside the tubing is also discussed. Specialized plots were used to calculate reservoir properties and then estimate average reservoir pressures.