bluuebunny/crossref_metadata_2025_split huggingface dataset:
Obtaining Reliable Laboratory Measurements
Authors: Sprunt Eve S. , Humphreys Neil V. 
Published: June 2014

E&P Exchange
Laboratory measurements on reservoir rock and fluid samples are required for many applications, including reserves determination, reservoir simulation, stimulation design, formation-damage assessment, and recovery monitoring. The costs of acquiring and testing samples are significant. Every attempt must be made to maximize the value added in making measurements. While the costs of laboratory measurements are small compared with the overall cost of field development, the financial impact is not. Decisions based on interpretation of the laboratory tests can make or break a project.
Before samples are acquired, define the goals of the measurement program.
. What are the business objectives in making these measurements?
. What are the consequences of not making these measurements?
. What business decisions will the measurements affect?
. What alternatives exist for obtaining these measurements?
. What are the consequences of making these measurements incorrectly?
The precision and robustness of commonly available measurements must be known to determine the nature of the data acquisition program. Balance the number of measurements and their accuracy. Unnecessarily narrow tolerances increase the costs of every step of the data-acquisition program. The objective may be reached more cost-effectively with a large number of qualitative measurements than with a few highly accurate ones. If measurement tolerances are broad, rule-of-thumb values may be adequate and new test data a luxury rather than a necessity. At the other extreme, small differences in measurements may critically affect decisions. Then, it may be necessary to customize existing testing procedures and develop new methods. Know the difference between the value of data and the cost.
Accuracy may not be constant over the entire measurement range. For example, measurements of permeabilities &lt; 1 and 1,000 md are significantly less accurate than measurements of permeabilities in between. Consider the anticipated values for properties when designing an experimental program. Tests that may be accurate on a rock with a permeability of several hundred millidarcies and 20% porosity may be highly erroneous on a sample with &lt;1-md permeability and 5% porosity.
Variances between different laboratories' measurements of basic properties are often larger than commonly assumed. If check samples are not used to ascertain measurement precision, unrealistically narrow limits may be cited. Laboratories fear that they will lose business if the competition claims greater accuracy.
The Gulf of Mexico Air Quality Study - An Industry Perspective
Authors: Shannon Brian E. 
Published: June 2014

SUMMARY
Section 328 of the Clean Air Act Amendments of 1990 required the EPA to promulgate a rule establishing air pollution control requirements for Outer Continental Shelf (OCS) sources. Congress exempted Gulf of Mexico OCS sources west of 87.5 degrees longitude (near the border of Alabama and Florida) pending the results of a "three year" study conducted by the Department of Interior (DOI) – Minerals Management Service (MMS). The study required an examination of the impacts of emissions from OCS activities in such areas that fail to meet the National Ambient Air Quality Standard (NAAQS) for either ozone or nitrogen dioxide. This paper reviews the MMS Gulf of Mexico Air Quality Study's (GMAQS) emission inventory development, historical ozone episode modeling, field sampling, and preliminary photochemical modeling results. Industry has developed a standardized spreadsheet to calculate emissions and a software package to allow operators to figure out the cost to control OCS sources for NO, and VOCs under the EPA's OCS Air Regulations (40 CFR Part 55). Cost estimates are provided for various regulatory scenarios currently being reviewed by the EPA and MMS.
Underbalanced Coiled Tubing Drilled Horizontal Well in the North Sea
Authors: Wodka Philip , Tirsgaard Henrik , Adamsen C.J. , Damgaard A.P. 
Published: June 2014

Abstract
Maersk Olie Og Gas AS has drilled a 3,309 ft long near horizontal drainhole with coiled tubing to a total measured depth of 11,000 ft in the Danish sector of the North Sea. The well was completed in May 1994 as a 3 1/2" open hole producer in the Gorm field chalk reservoir
Part of the well was drilled at underbalanced conditions with oil production rates of up to 1,100 stb/d during drilling. Conventional well test equipment was used for handling returns. A nearby process facilities platform supplied lift gas and received the produced hydrocarbons during the drilling phase.
Worth noting are the penetration of several chert layers, the fairly long reach, and the application of geo-steering Indications are that the well productivity is significantly improved compared to that of a conventionally drilled well, but problems were experienced with borehole stability in a fractured region.

Introduction
Maersk Olie og Gas AS (Maersk Oil) produce approximately 180,000 stb/d of oil from soft chalk reservoirs in the Danish sector of the North Sea. The largest producing fields have reached a stage, where the majority of the development activities concentrate on infill drilling and implementation of secondary recovery by means of water injection. Since 1989, development activities have almost exclusively been based on horizontal wells with a total of 78 wells drilled in five fields. Most of these wells are completed with a 7" cemented liner and perforated in multiple intervals with each interval straddled by 4 1/2" tubing (PSI system) for stimulation and production management purposes (Ref. 1 and 2).
As part of the continued efforts to produce the reservoirs in a cost effective manner and increase ultimate recovery, the emerging technology of coiled tubing drilling is seen as one possible method of obtaining low cost well re-entries, e.g for sidetracking and well extensions. It is recognized that the attractiveness of this technique depends on the long term production performance, including borehole stability, and the capability to decrease the costs, e.g. by performing the drilling operation from existing wellhead platforms on the relatively small wellhead platforms in the Danish sector, limited deck space necessitating placement of equipment on two bridge connected wellhead platforms and limited crane lifting capacity are the main problems in this respect
No field proven method had been developed for sidetracking from a horizontal well with a coiled tubing drilling assembly. Therefore, surface tests were initiated onshore in a coiled tubing test loop during August 1993. The objective was to test the technical feasibility of performing sidetracks and well extensions from existing horizontal 4 1/2" PSI completions with 3.688" restrictions. Several methods were tested, and a successful horizontal through tubing sidetrack was achieved already in the second attempt.
In Situ-Segregated Production of Oil and Water – A Production Method With Environmental Merit: Field Application
Authors: Swisher M. D. , Wojtanowicz A. K. 
Published: June 2014

Abstract
This paper describes field implementation of a new production method, the water drainage-production system for oilfields with bottom water coning problems. The method enhances the production rate of water-free oil while eliminating hydrocarbon contamina-tion of produced water.
The new method was used in a Wilcox sand in North Louisiana to resolve the problem of excessive water cuts experienced in conventional wells. Typically, for a conventional well in this area, a water problem would develop in 60–90 days after the beginning of oil production. The excessive water cut would cause a reduction of the oil rate from 35 BOPD initially to 12 BOPD with 97% water cut.
In this application a new well was drilled through the oil and water columns and dual-completed in both zones. The water-drainage completion (gravel packed) was isolated from the oil completion with a packer and 3-1/2" tubing. A downhole progressive cavity pump lifts the water in the tubing, while the formation pressure drives the water-free oil up the annulus between the tubing and 7" casing. To date, after 12 months of production, the oil production rate is averaging 45 BOPD, water-free.
Mathematical modeling was used to help in the design of the completion. Shown in this paper is a computer-generated analysis of the drainage-production system's performance. The analysis helped to determine the oil and water rates and geometry of the well's com-pletion.
Chemical analysis of water produced in the new method shows minimal contamination with polynuclear aromatic hydrocarbons (PAH), 11 parts per billion. This is an over 50-fold reduction compared to PAH contamination of water produced conventionally. Also, no contamination with Oil and Grease was measured with a detection limit of 2 mg/1.
Measurement and Enhanced Monitoring of BTEX and VOC Emissions from Glycol Dehydrators
Authors: Rueter Curtis O. , Reif Dirk L. , Menzies William R. , Evans Jarnes M. 
Published: June 2014

Abstract
The Clean Air Act Amendments of 1990 and activities by several states have resulted in increasing regulatory pressure on emissions of benzene, toluene, ethylbenzene, and xylenes (BTEX) and total volatile organic compounds (VOC) from glycol dehydration units. There are no standard sampling and analytical methods established by regulatory agencies for determining emissions from glycol dehydrators, and the methods initially used by the industry showed significant variability in results.
To address this lack of methods, the Gas Research Institute (GRI) began an effort to develop measurement methods and emission estimation techniques for glycol dehydrators. Ten methods were evaluated based on the criteria of ease of use, cost, and precision and bias in a series of field experiments at ten sites. The results of the project showed that GRI-GLYCalc™ should be used to initially screen a large number of units and that atmospheric rich/lean glycol measurements should be made to refine these initial estimates.
GRI has also initiated efforts to assist the industry in complying with enhanced monitoring requirements for glycol dehydrators. These enhanced monitoring protocols may be based on using condenser temperatures in conjunction with computer programs such as GRI-GLYCalc. Additional test data will be collected using the methods developed in the previous efforts to validate the computer program predictions for condenser control efficiencies.
The Mitigation of NORM Scale in the Gulf Coast Regions of Texas and Louisiana: A Laboratory and Field Study
Authors: Oddo John E. , Zhou Xinliang , Linz David G. , He Shiliang , Tomson Mason B. 
Published: June 2014

ABSTRACT
Some oil field scales have the potential to contain regulated levels of naturally occurring radioactive materials (NORM). It is estimated that between 300,000 and 1,000,000 tons of NORM scale are produced each year. In addition, scale deposition in producing facilities negatively impacts rates of production and is expensive to treat and remediate. The most common NORM containing scale is BaSO4, or barite. This paper presents the results of a Gas Research Institute study that investigates the causes of NORM scale formation and mitigation techniques employed in the field.
Chemical threshold scale inhibitors are generally employed to inhibit scale formation in production systems. However, there is little agreement on which scale inhibitor is most effective with respect to differing water chemistries, temperatures and conditions encountered. Results using a GRI patented inhibitor evaluation apparatus can be used to determine the most effective inhibitor for a specific field application. Work in the Michigan Basin presented in the last conference indicated that a phosphinopolycarboxylate was most effective against NORM barium sulfate scale formation at low temperatures in relatively fresh water. Further work in this study identifies phosphonates as being more effective in the higher ionic strength (TDS) waters and higher temperature regimes that can be expected in the Gulf Coast. A matrix of ionic strength and temperatures with inhibition response is presented.
Although more NORM fields were studied, two are presented in detail. In these fields, three causes of NORM scale were identified; 1) Incipient scale in a well due to production; 2) Scale formation due to previous seawater floods and; 3) The commingling of waters from different zones or wells. Field treatment techniques employed in the two fields studied are summarized in the paper.
Inhibitor squeeze procedures were also studied in the laboratory and in the field. A squeeze simulation apparatus was constructed to research inhibitor squeeze practices in the laboratory. Results from this work resulted in successful inhibitor squeeze applications in the field. The inhibitor squeeze apparatus and the field results are discussed in the paper. Squeeze life has been extended from an average of two to six months to two to three years or more as a result of the work.
Application of an Area of Review Variance Methodology to the San Juan Basin New Mexico
Authors: Dunn-Norman S. , Warner D. L. , Koedoritz L. F. , Laudon R. C. 
Published: June 2014

Abstract
When the Underground Injection Control (UIC) Regulations were promulgated in 1980, existing Class II Injection wells operating at the time were excluded from Area of Review (AOR) requirements. EPA has expressed its intent to revise the regulations to include the requirement for AOR's for such wells, but it is expected that oil and gas producing states will be allowed to adopt a variance strategy for these wells.
An AOR variance methodology has been developed under sponsorship of the American Petroleum Institute1. The general concept of the variance methodology is a systematic evaluation of basic variance criteria that were agreed to by a Federal Advisory Committee. These criteria include absence of underground source of drinking water (USDWs), lack of positive flow potential from the petroleum reservoir into the overlying USDWs, mitigating geological factors, and other compelling evidence.
The AOR variance methodology has been applied to oilfields in the San Juan Basin, New Mexico. This paper details results of these analyses, particularly with respect to the opportunity for variance for injection fields in the San Juan Basin.
Development and Practice of Separate Layer Production Technique in Daqing Oilfield
Authors: Wang Zhou , Chaoyang Xie , Jingshen Li , Fengshan Wang 
Published: June 2014

Abstract
This paper describes development and applications of separate layer production technology, which facilitates full exploitation of the potential of each oil-bearing layer. The technology has evolved as water cut has increased in Daqing oilfield and focus has shifted to thinner, lower productivity layers. In Daqing field, 11 kinds of separate layer water injection strings, which can be divided into two main categories (hydraulic inflatable and compressional), 33 kinds of separate layer production (water shut off) strings divided into four main categories (including integral, slip support releasing, drill-able and pressure balance), four separate layer fracturing techniques (including sleeve separate layer, limited entry completion, multi-frac and positioning balance) have been developed.
A Study of Infill Pattern in the Later Period at High Water Cut Stage to the Main Reservoir in the Central Portion of the Saertu Pool
Authors: Shiyuan Zhao , Hongyin Gao , Hongfu Jiang 
Published: June 2014

Abstract
The main reservoir of the Daqing field, the PI reservoir, was evaluated after total water cut had increased to about 90%. The location of high residual oil saturation was correlated with the depositional environment. Recompletion and redevelopment plans were formulated for each lithology. Wells were selectively perforated and additional infill wells were drilled. Finally, a polymer flood was initiated. It was concluded that the reservoir should be perforated twice to increase the volume swept by waterflood before injecting polymer.
Variations of Petrophysical Parameters After Sandstone Reservoirs Watered Out in Daqing Oil Field
Authors: Hongxing Zhang , Qingnian Liu , Fengqin Li , Yingping Lu 
Published: June 2014

Abstract
Based on lab data this paper summarizes differences of petrophysical parameters of sandstones in Daqing Oil Field which were not watered out before waterflooding and were watered out after waterflooding. Pore throat dimensions, relative permeability, and wettability change with prolonged waterflooding. Using internal waterflooding at an early stage is a method of maintaining the reservoir energy and achieving long — term high and stable production. Injecting a great quantity of water for a long time is an effective means of enhancing oil recovery of reservoirs for Daqing Sandstone Oil Field.
Field Test of Immiscible CO2 Drive in Daqing Oil Field
Authors: Jingcun Zhang , Shangxian Xie , Peihui Han , Jiabao Chen , Zhenghua Zhang , Encang Guo 
Published: June 2014

Abstract
The choice of water alternate carbon dioxide flooding in Sanan was decided based on prefeasibility studies on EOR methods suitable for Putaohua reservoir in Sanan area of Daqing Oil Field. This process was first implemented on one pilot, before any industrial extension. This paper introduces the pilot test, evaluates the effects of CO2 drive and analyzes behavioral characteristics of the test.
Relationship Between Reasonable Injection-Production Ratio and Pressure Level in Development Area of Southern Saertu Reservoir, Daqing Oilfield
Authors: Qixin Li , Yuzhuo Wang , Huanzhong Dong 
Published: June 2014

Abstract
Using the principles of seepage mechanics, this paper analyzes the interrelationship between formation pressure and injection - production ratio and the influential factors. On the basis of a mechanical study, it quantitatively analyzes the pressure history of each area by means of a mathematical statistic method and the controlling factors, and the effect of every factor on formation pressure. It furnishes a scientific basis for the effective and rational control of the Southern development area of the Saertu Reservoir and each sub-area.
The Discrete Newton Method of the Three Parameters Inversion in Electrical Logging
Authors: Yang Cao , Jiaqi Liu , Wei Yang , Yousheng Fu 
Published: June 2014

Abstract
Log analysts are always interested in the problem of determining the invaded zone resistivity, Rxo, the virgin formation resistivity and the diameter of the invaded zone, D, simultaneously, using the logging tool responses of the deep and shallow laterolog 3. In this paper, the problem of multiple parameter identification in electrical logging is reduced to a partial differential equation. Using the Discrete Newton method and the regularization method, the mathematical formulas of inverting three parameters are derived. Thus, an iterative method of simultaneously solving Rxo, RT and D is obtained.
To test this method, some numerical computations have been made. The computational results show that when no noise is added, the mean relative errors of inverting Rxo, RT and D are 0.67%, 0.47%, and 2.28%, respectively. When 10% noise is added to the resistivities of the adjacent formation, the mean relative errors are 2.65%, 0.92%, and 5.39%, respectively. This method has been used to deal with the real measured data. This method can be used widely to direct log interpretation and eliminate the interpretation chart.
Monitoring and Controlling of Oil and Gas Cross Flow During Production of Daqing Lamadian Laminated Oil Field with Gas-Cap
Authors: Baofa Ji , Zhengshun Xu , Jianxin Wang 
Published: June 2014

Abstract
Daqing Lamadian oil field is the largest oil field with a gascap in China. Monitoring, controlling and adjusting techniques have been used extensively to minimize cross flow. An inverted nine-spot pattern was used in the oil-bearing area. Gas-bearing layers were not perforated and there was a 400 to 600m buffer zone of oil and gas migration left between oil-and gas-bearing areas. A monitoring system for gas-cap performance was established. Flow between the oilbearing and gas-bearing layers has been successfully controlled and a relatively stable oil-gas interface has been maintained for 20 years.
Mechanism of Cyclic in Waterflooding in Vertically Heterogeneous Reservoirs
Authors: Qingfeng Yuan , Bingyu Ji , Jiping Yang 
Published: June 2014

Abstract
From Darcy's law of two phases (oil and water), an analytic expression for oil and water vertical cross flow including gravity cross flow, capillary cross flow and additional cross flow under the effect of cyclic waterflooding is developed. Based on function J, this paper analyzes the vertical cross flow characteristics of capillary and its influence on production, explains the essential distinction between cyclic waterflooding and conventional waterflooding.
High Integrity Pressure Protection Systems For Production Applications
Authors: Langvik S. , Aarebrot E. 
Published: June 2014

Abstract
Through the use of a High Integrity Pressure Protection System (HIPPS) the flare capacity of a wellhead platform can be reduced to the flowrate required for depressurisation. The HIPPS may also be used to reduce the flare capacity of a process plant. By the use of HIPPS, the discharge of hydrocarbons or carbon dioxide due to venting/flaring is reduced.
This paper describes the development of HIPPS for the Sleipner B-platform offshore Norway. A 20" multiphase pipeline is protected against overpressure by two 20" quick acting shut down valves (QSV) installed in series, instead of pressure safety valves. The valves have been qualified for operation in wellstream at a shut-in pressure of 336 bar, and have a closing time of 2 seconds. Each of the QSVs has independent, fail safe instrumentation cirquits. A parallel train of QSVs has been installed due to the testing requirements. The estimated saving using HIPPS on SLB was $ 25 mill.
The paper also discuss existing and new applications of the HIPPS.