bluuebunny/crossref_metadata_2025 huggingface dataset:
Anisotropic Permeability Measurement of Porous Media: A 3-Dimensional Method
Authors: Asadi Mahmoud , Ghalambor Ali , Rose Walter D. , Shirazi Mogdeh K.
Published: December 2007

A simple model is developed to measure principal permeabilities of anisotropic media. The developed model presents an accurate procedure to measure principal permeabilities of both two and three-dimensional anisotropic media. A special core cutting procedure is developed to measure principal permeabilities of an anisotropic medium under isotropic conditions. This procedure enables flow rate measurements at upper and lower sections of an anisotropic sample end face. A logarithmic plot of upper flow rate to lower flow rate ratio versus the sample's end-face angle, results in the precise measurement of the end-face angle which once the sample is shaped to that angle flow velocity vector is uniform and parallel to the sample's long axis over the entire core length. Once this is accomplished, similar procedure is applied to the left and right halves of the core sample's end- face. This procedure assures the elimination of end effect flow pattern, which is created due to the anisotropicity of the system. Measurement of flow rate in an arbitrary Cartesian axis system results in determination of nine elements of a second rank permeability tensor. Through the eigen-value theory, principal permeabilities (Kmax, Kmin, and Kint) of an anisotropic medium are then calculated.
Integrated Amplitude Versus Offset (AVO) Approach for Delineating Stratigraphic Traps
Authors: Yusof Mohd Azudin Bin Mohd
Published: December 2007

Exploration for Stratigraphic trap is of higher risk but the reward can be spectacular since the closure is not limited to structural spill point. Specialized exploration tools such as 3D seismic have become economically feasible and the use of super computers has resulted in improvement in data quality and interpretation. 3D marine seismic data acquisition has become more efficient and even 3D AVO is becoming cheaper. However, integration of well data or nearby well information is highly recommended to reduce risk since high amplitudes visible on seismic data do not necessarily related to Direct Hydrocarbon Indicator (DHI). As a prerequisite, seismic processing steps need to be evaluated carefully to preserve amplitudes. This paper is based on a test AVO processing and interpretation done on Field A in the Malay Basin. Result from the test line processing and interpretation has broadened in-house expertise on the AVO technique. The analysis could also be used to upgrade the probable or possible reserves to proven reserves and to delineate stratigraphic traps.
Integrating Pressure Data from Formation Tester Tool and DST to Characterize Deepwater Fields, East Kalimantan, Indonesia
Authors: MacArthur Jack , Vo D. T. , Palar Steve , Terry Albert , Brown Trevor , May Ron
Published: December 2007

In the last three years, two significant commercial hydrocarbon accumulations in Indonesia deep waters of the Makassar Strait were discovered. These fields are located approximately 16 miles northeast of the giant Attaka Field in 1400 ft to 3400 ft of water.

To date more than 40 exploration and appraisal wells have been drilled in both fields and extensive pressure data has been collected by formation tester tool and drillstem testing tool. The pressure data, used with other data such as seismic and well logs, has enabled Unocal Indonesia to characterize deepwater turbidite sand reservoirs.

In this deepwater environment, DST is used selectively and only with strong justification due to its prohibitive cost. Instead, the use of the pressure testing tool is pushed to its limit in order to gain extensive pressure, rock and fluid properties data, conventionally obtained by DST.

This paper will show the experience of Unocal Indonesia to characterize deepwater reservoirs by means of pressure data from the formation tester tool and DST's to complement geological and seismic data interpretations. Reservoir characteristics such as fluid type, fluid contacts, reservoir connectivity and sand geometry can be inferred from the pressure gradients and pressure transients. These data are used in constructing reservoir fluid flow models for field development plan.
Managing Assets under Uncertainty
Authors: Davis J. P. , Fletcher A. J. P.
Published: December 2007

The management of exploration, appraisal and production is a problem of leveraging the expertise of a company to maximise the potential of the asset. The word company is very appropriate here as it describes well the gathering of disparate disciplines focussed on a specific purpose. The management of the asset is a process that requires the gathering and integration of evidence of many different types from different experts with all kinds of uncertainties.

This paper describes a methodology and tool for handling that process in multidisciplinary teams. It is a generic technology that can be applied across the business. It is being applied to estimating the dependability of reserves estimates, estimating the likelihood of success of a prospect, enterprise resource management, technology selection and condition monitoring. Case studies are presented.

The method has three elements:

a process model of the management process highlighting dependencies, a record of the attributes of the process, and, a rich uncertainty calculus for the integration of uncertainties.

The uncertainties are expressed using interval probability which allows the evidence for success to be separated from the evidence against success. The whole approach is implemented in a highly visual graphical environment that allows new users to build new models very quickly.

Case studies have shown that the added value comes not just from the numerical assessment of the overall dependability of the project, but from improved communications both inside and outside the team. A shared understanding of the situation is developed and misunderstandings resolved. The model gives a one page pictorial overview of where the project stands, showing where the vulnerabilities and sensitivities are. In terms of corporate memory it provides an easy to assimilate record of how the conclusions were reached and a shared memory for the team.
Integrated Modelling and Uncertainty Management of a Gas Injection Scheme in a Highly Fractured Carbonate Reservoir
Authors: Woodhead T. J. , Willemse E. J. M. , Mills R. M.
Published: December 2007

Multiple scenario modelling methodology has been used to study gas injection in a fractured carbonate reservoir to facilitate an increase in productivity and ultimate field recovery as a result of reservoir repressurisation. The complex physical processes involved in the production mechanism, and a relatively sparse data set, highlighted the underlying problem of making predictions based on reservoir models for which a large degree of uncertainty exists. These uncertainties have a significant impact, both in the understanding of the reservoir fracture geology and in the data used for describing the fluid flow processes. A novel approach was developed to represent uncertainty ranges in model forecasts in which multiple history-matched simulation models were constructed to represent the impact of a range in each of the uncertainty parameters on the forecast. The methodology builds on an approach previously reported in Bentley and Woodhead (Ref.1). The results were then combined statistically into probability distributions of recovery profiles. The results show clearly the large impact of data uncertainty on incremental recovery arising from the gas injection scheme. The treatment of uncertainty presented here is a step forward in the modelling methodology for mature assets in which multiple scenario modelling has to be constrained by the necessity to history match all model realisations against production data.
Electrical Dissipation Factor: A Novel Way To Detect Changes in Shale Water Content
Authors: Adisoemarta P. S. , Heinze L. R. , Morriss S. L.
Published: December 2007

The alteration of shales, caused by adsorption of water while drilling, is one of many contributors to the wellbore stability problem that costs the industry in the order of $ 400-500 million annually (Bol et.al., 1992). This alteration of shale problem has acquired a logging perspective due to the increasing use of measurements while drilling. The capability of taking real time and time-lapse measurements while still drilling introduces the possibility of detecting a swelling problem while something can still be done about it.

The objective of this study (Adisoemarta, 1999) is to observe the changes of complex electrical characteristic of shale as a function of water content. The word "complex" in the electrical characteristic term means this study will not only observe the "in-phase" electrical response but also the "out-ofphase" response.

By taking the ratio of the in-phase to the out-of-phase electrical response, this study found that this ratio, the dissipation factor, changes linearly as a function of shale water content. This method can be easily applied to both the drilling / wellbore stability or formation evaluation areas.
Benefits of Using Automation Software for Gas Production Optimization
Authors: Ray Louis , Juran Kenneth
Published: December 2007

This paper describes the cash flow enhancement benefits of using automation software for gas production optimization. Efficiently monitoring well and facility operations, analyzing well performance, and accurately predicting problems with software optimization tools has resulted in significantly decreased failure rates and increased production per well.

The automation software allows producers to move from a reactive mode to a proactive mode. Wells become more stable, and analysts can spend more time fine tuning operations for maximum production rather than fixing emergencies. In short, the networked automation software system calls on computers and other devices to handle the manual and repetitive work of monitoring wells and facilities, as well as collecting and crunching numbers.

The optimization process goes beyond basic operations, but extends into production optimization involving well testing, facilities monitoring and alarming, production monitoring, and gas injection. The net effect is increased runtime and arrested decline curves, resulting in more reserves.
Tiltmeter Hydraulic Fracture Mapping in the North Robertson Field, West Texas
Authors: Mayerhofer M. , Demetrius S. , Griffin L. , Bezant R. B. , Nevans J. , Doublet L.
Published: December 2007

This paper presents both downhole and surface tiltmeter hydraulic fracture mapping results of five fracture treatments (in two wells) in the Clearfork formation located in the North Robertson Field, West Texas. This field is under waterflood and both injectors and producers are generally fracture treated in three stages at depths of roughly 6,000 to 7,100 feet. Surface tiltmeter mapping was performed on all five treatments to determine hydraulic fracture azimuth and dip. Downhole tiltmeter mapping was performed on 2 treatments in one well to determine the fracture geometry (height and length). In addition, other diagnostic technologies such as fracture modeling and radioactive tracers were used and their results and conclusions are discussed in conjunction with tiltmeter mapping. Understanding hydraulic fracture growth is of critical importance for evaluating well placement and the risk of communication between producers and injectors and to assess fracture staging, perforating and well performance issues.
A Prospectors Dream Come True: Tons of Unique Data, All Under One Roof!
Authors: Barrett Damian , Trentham Bob
Published: December 2007

Have you ever worked on a prospect that all you needed to finish it off wasa mud log or core analysis on that one older well in your cross-section? Or youdrilled your first well in your prospect and needed a full scale offset log tocorrelate with on location? Now you can have access to the largest and uniquecollection of data in the Permian Basin - all under one roof, The MidlandEnergy Library (MEL). This old, new and unique data has not been lost, it hasbeen donated to MEL.

Mission Statement

The Mission of MEL is to collect, preserve, catalog and exhibit scientific, geological and engineering data gathered by the petroleum industry into aworking library for use by industry professionals, educators, students andother members of the interested public.

Rare Specialty Data

MEL has over 1550 DST's and 8570 mud logs in Texas, over 350 DST's and 2400mud logs in NM and over 6750 core reports in Texas and NM and over 55,000sample logs. One to 4000 ownership map spotted weekly with new wells from PIweekly reports. Gravity and Magnetic maps, velocity surveys, dipmeters andsynthetics. There are even company donated prospect files that are just waitingto be found and drilled. There are over 550,000 Fusulinid slides withmicroscopes and a petrographic microscope with a camera. The collections arefrom Hollingsworth, Wendell Stewart, Van Howbert, Ed Volger and John M. Cys.Byrums 15 volume set of rules and regulations. There are over 670,000 Texaslarge and small-scale logs and 177,000 NM large and small scale logs. One ofthe best resources is the friendly, helpful staff that knows where everythingis and can quickly help you find what you need or do tech work for you for aminimal charge.

Poster Session

You will not want to miss seeing this poster session. You will get to seesome of this unique data, pictures of where it is stored; books with listingskof the special core, DST, and mud log data sorted by operator or location foryou to look through. If for some reason, you did not make it to the conferenceto see the poster, you will be able to view it onlineat: http://www.texasonline.net/mel/index.htm. However, the best way to learn more about the library is to call in and set anappointment for your personal tour.

Vision Statement

The vision of the library is to become the primary respository and atabasefor scientific, geological and engineering date relating to the United Statesoil and gas industry and to make this data abailable to the public through aworking library. It is further vision that by becoming the databse for theUnited States oil and gas industry, the library can assist the City of Midlandin achieving its goal of becoming the headquarters city for the independentsegment in the United States oil and gas industry.
Material Balance for Multi-Layered, Commingled, Tight Gas Reservoirs
Authors: Kuppe Frank , Chugh Shelin , Connell Paul
Published: December 2007

A simple spreadsheet model has been developed to estimate Original Gas In Place (OGIP), layer productivity and recoverable reserves for wells with commingled production, completed in multi-layered tight gas reservoirs. Differentiating the productivity between multiple layers of contrasting permeability is old technology. This model, however, replicates the observed material balance trend while also honouring total well production data by varying layer properties. The P/Z trend of the higher permeability layers and lower permeability layers is mapped to "envelope" the productivity index (PI) weighted P/Z curve that is used to match historical data.

This technique has been made applicable to the multi-layered reservoir environment by grouping the various kh terms, from all "high permeability" layers, into one model layer and all "low permeability" kh values into the "tighter" model layer. Published literature1 has already shown that the generation of the layer P/Z curves is applicable for reservoirs with permeability in the range of 0.1 to 10 md. The model has been successfully applied to match and predict the productivity for various wells in Cooper Basin fields, with permeability in this range, and P/Z plots that exhibit curvature. Case studies show that any change in bottom hole pressure conditions (eg. compression) or skin (eg. stimulation) can also be accounted for in the model. Various simulation models have been generated to confirm this technique's applicability to wells in Australia's Cooper Basin, and to establish the PI weighting method.
Economics of CO2 Sequestration in Coalbed Methane Reservoirs
Authors: Wong S. , Gunter W. D. , Mavor M. J.
Published: December 2007

Enhanced Coalbed Methane Recovery (ECBM) is presently not commercial due to the high cost of compression and capture of the injection gas either carbon dioxide (CO2) or nitrogen (N2). Recently, the necessity to reduce greenhouse gas emissions has provided a dual role for coalbeds – as a source of natural gas and as a repository for CO2. The second role arises because of the storage mechanism for gas in coal. Unlike CO2-enhanced oil recovery processes, CO2 injected during ECBM recovery is strongly adsorbed onto the coal, and in a relatively homogeneous reservoir is not expected to break through to the production wells until the bulk of the coalbed methane (CBM) reservoir is swept of methane. This provides a huge CO2 storage potential in coalbeds throughout the world. However, based on current economic factors, it makes more sense to partially deplete the coal reservoir of methane before injecting CO2. The exact strategy depends on two economic factors, the costs and credits for sequestration of CO2 and the natural gas sales price. CO2 credits would have a major effect on the production strategy used for CBM, and would favor early use of ECBM. An example is used later in this paper to illustrate this point that takes into account the differences between "gross CO2" sequestered (CO2 captured), and "CO2 avoided" (net CO2 sequestered).
Brine Mixing in Waterflooded Reservoirs and the Implications for Scale Prevention
Authors: Mackay E. J. , Sorbie K. S.
Published: December 2007

Although waterflooding is a common method for increasing oil recovery, certain production problems may arise after water breakthrough. In addition to affecting oil recovery, these problems may also have an adverse impact on the environment. One particular production problem is mineral scale formation due to mixing of incompatible brines. For example, barium sulphate formation in the production well and tubulars occurs in many oilfields when sulphate rich injection water (usually seawater) mixes with barium rich formation water close to or in the wellbore. Understanding where the scale forms is important when attempting to prevent it damaging productivity. However, there is some field evidence which suggests that scale deposition deep within the reservoir may occur without having any adverse effect on oil recovery. This paper addresses the two related issues of (i) where sulphate scales form, and (ii) whether any operator action is required where wells are producing lower concentrations of scaling ions than would be expected if scale formation was completely inhibited. These issues were raised by two papers presented at the 1st SPE International Symposium on Oilfield Scale in January 1999, and it was the ensuing discussion which initiated the present study.

All of the principal mechanisms of brine mixing in waterflood displacements are considered and modelled. This leads to a fuller understanding of where - and to what extent - brine mixing will occur within the reservoir. As a consequence, we may address the questions of why scale deposition deep within the reservoir may in certain circumstances occur, while in other situations it is probably very limited. It is demonstrated that, although connate water in the oil zone is mobilised by injected water, typically little mixing would be expected far from the wellbore. Conversely, as the different brine types, which have retained the scaling ions, approach the wellbore, mixing and scale deposition are to be expected. Mixing in the aquifer where brine mobility can be much higher, however, may result in lower than expected ion concentrations. The reduced ion concentrations may be caused by scale dropout, or by mixing of formation brines with different compositions, or by a combination of both mechanisms. In either case, modelling of such processes has confirmed that they are possible explanations for low barium levels. The impact of scale dropout deep in the reservoir on the design of inhibitor squeeze treatments is discussed.
An Experimental Study of Removing Iron Sulfide Scale from Well Tubulars
Authors: Nasr-El-Din H. A. , Fadhel B. A. , Al-Humaidan A. Y. , Frenier W. W. , Hill D.
Published: December 2007

This paper describes the effect of chemical interactions on the efficiency of removing iron sulfide scale. Most types of iron sulfide can be removed by inorganic acids. A corrosion inhibitor (amine-type chemical) is added to the acid to protect the well tubulars. In addition, a hydrogen sulfide scavenger (aldehyde type) is used to prevent precipitation of elemental sulfur and iron sulfide. Other chemicals are also added to the acid to enhance acid-contact with the scale and prevent precipitation of iron once the acid is spent. Laboratory tests were conducted to evaluate the effect of chemical interaction on the efficiency of removing iron sulfide scale. The influences of various acid additives (anionic, cationic and non-ionic) on the dissolution power of the acid and the corrosion of oilfield steels were examined over a wide range of parameters.

Results, Conclusions

Laboratory data indicated for the first time that the ability of the acid to remove iron sulfide scale depends, among other factors, on the ionic character of the acid additives. Corrosion inhibitors, which are used to protect the casing and well tubulars from the acid, were found to adsorb on the iron sulfide scale and inhibit acid reaction with the scale. Hydrogen sulfide scavengers, aldehyde type chemicals, were found to inhibit acid reaction, especially at high concentrations. A similar trend was noted with methanol and citric acid. On the other hand, TX-100 (a nonionic surfactant) and SDS (an anionic surfactant) was found to enhance the dissolution of iron sulfide by the acid.

Acid additives, especially anionic surfactants and mutual solvents were found to affect the ability of the corrosion inhibitor to protect the base metal.
Fracture and Production Data Integration Using Discrete Fracture Network Models for Carbonate Reservoir Management, South Oregon Basin Field, Wyoming
Authors: Parney R. , Cladouhos T. , La Pointe P. , Dershowitz W. , Curran B.
Published: December 2007

This paper describes the development of a discrete feature network (DFN) model for the South Oregon Basin field in the Big Horn Basin of Wyoming. This DFN model is being developed to support well placement and gel treatment in order to recover previously bypassed oil in this highly heterogeneous, structurally controlled carbonate reservoir.

The DFN model developed in this paper is based on data from outcrop studies, fracture and lithologic data from wells and lineament maps from 3D seismic. The model is calibrated against tracer test results.
Multilateral Well Leg Re-Entry Made Possible With a Unique Coiled Tubing Downhole Tool
Authors: Lambert M.
Published: December 2007

In recent years, new drilling technologies have changed the traditional well profile to increase field productivity. The majority of new wells now being drilled have one or more horizontal legs in order to maximize the drilled hole interface with the rock formation, thereby increasing production from a single wellhead. New techniques to manage and service these wells have also emerged, however, re-entry into open hole or uncontrolled multilateral junctions can be difficult.

A new coil tubing tool or lateral entry guidance system has been developed to help locate and steer into these multiple completions. The tool uses a unique methodology for use with standard coil tubing to gain access into lateral legs. No special electrical conduits are required to operate the tool and tool function is automatic when downhole. A precise series of pressures and flow rates from a surface pump are the only requirement to operate the tool. The tool can deliver most stimulation fluids directly via the coiled tubing or piggyback other coil tubing tools.
Integration of Coiled Tubing Underbalanced Drilling Services to Improve Efficiency and Value
Authors: Thatcher Darren A. A. , Szutiak Greg A. , Lemay Marc M.
Published: December 2007

Although Coiled Tubing Underbalanced Drilling has proven advantageous in reducing formation damage, increasing penetration rates, and potentially eliminating well stimulation treatments it is still regarded as one of the higher risk service operations being performed in the world today. Some operators who have utilized Coiled Tubing Underbalanced Drilling previously site that unreliable downhole tools, long rig-up times, and hole cleaning issues contribute to higher costs and unacceptable risks involved with this application. In order to maximize the advantages of Coiled Tubing Underbalanced Drilling and minimize the perceived risks, careful assessment and close scrutiny of each aspect of the operation must be carried out.

This paper outlines the planning and execution responsibilities of two companies working synergistically to provide an operator with their expertise in each area of service. Contracting integrated work-over services for a Coiled Tubing Underbalanced Drilling project on a well where previous drilling operations had failed was felt necessary by the well operator to maximize the wells potential, increase the probability of success, and minimize the risk involved. Well history of the previous drilling attempts, pre-job planning and engineering, equipment and tool specifications, operational execution, and benefits achieved through an integrated approach are discussed. The results of the drilling operation and suggested improvements of the integrated service approach are also reviewed.
Rotation of Coiled-Tubing
Authors: Newman Ken , Stein David , Ackers Mick
Published: December 2007

It has long been known that CT rotates during its life because the orientation of the seam weld at the end of the CT varies. This rotation changes the bending plane and thus the fatigue life of the CT. None of the current CT fatigue and deformation (elongation and diametrical growth) prediction models considers this rotation.

An experimental rotational-orientation measuring device (ROMD) was developed to measure the rotational orientation of the seam weld as the CT runs in and out of the hole. This device was used to record the rotation of CT strings in various applications. Results from these runs are presented.

The affects of rotation on fatigue life are quantified using an existing fatigue model. Some fatigue test results are presented in which the CT was rotated between bends. Both the modeling results and the experimental results show that the fatigue life increases due to rotation.
New Cutting Structure Design Improves the Performance of the PDC Bit
Authors: Sun Mingguang , Zhang Yunlian , Yang Yukun , Huangtao _ , Zhao Jinhai
Published: December 2007

The conventional PDC bits have seldom been successfully used in the inter-bedded formation since Shengli Oilfield was discovered in 1964. The inter-bedded formation contains hard dolomite, limestone stringers, abrasive sands etc. In this kind of formation, rocks alter between soft and hard quite frequently. Cutters of the PDC bit are prone to damage because of bit vibrations while drilling.

This paper studies the characteristic of the inter-bedded formation in Shengli oilfield, analysis the damage reason of PDC cutters, presents a new method of cutting structure design and describes the work principle of it. According to the new design method, a new PDC bit with new cutting structure is developed, in which two or three types of cutter are arranged on each blade. These cutters are arranged in special way to protect each other while drilling, and then extends the bit life.

In field tests, the new designed PDC bit was successfully used in inter-bedded formation drilling. Comparing with conventional roller cone bit(or PDC bit) used in same intervals, drilling footage of new designed bit increases by more than one time and ROP increases by 30-70%. Economic benefits have been achieved. The new designed bit is being widely used in Shengli Oilfield.
Successful Sandstone Acid Design Case Histories: Exceptions to Conventional Wisdom
Authors: Kalfayan L. J. , Services B J , Metcalf A. S.
Published: December 2007

The most common purpose of sandstone matrix acidizing is removal of siliceous particles such as formation clay, feldspar, and quartz fines that are restricting near wellbore permeability, plugging perforations or gravel packs. This is accomplished with injection of acid formulations containing hydrofluoric (HF) acid or its precursors, as HF is the only common acid that dissolves siliceous particles sufficiently. Such plugging particles may be naturally occurring or may have been introduced into the formation during well operations. The formation damage such particles can cause may occur during any well operation, including drilling, completion, workover, stimulation, and production. HF acid reaction in sandstones is rapid, therefore only matrix formation damage very near the wellbore can be expected to be treated effectively. Nevertheless, removal of near-wellbore formation damage can result in several-fold increases in well productivity. However, the risk of failure is fairly high.

Beginning with the groundbreaking work of McLeod1, sandstone acidizing guidelines based on mineralogy and permeability considerations have been developed and expanded in recent years, sometimes in the interest of increasing the frequency of treatment success. Selected acid types and concentrations, in particular, are now often based on such guidelines. HF acid guidelines can be useful in providing a starting point in the treatment design process. However, indiscriminate reliance on them can still lead to disappointing results. Reliance on such guidelines alone violates their original intent, and diminishes their meaning.

This paper presents case studies in which successful sandstone acidizing treatment designs were unexpectedly out of step with conventional guidelines which did, however, provide meaningful starting points in acid selection in some cases. Successful treatment procedures were instead developed from diagnosis of formation damage contributors, evaluation of production and stimulation histories, and a philosophy of flexibility and continuous improvement in stimulation procedures and execution practices. Case examples include well and field-wide treatments conducted in North America, South America, and the Far East.
Structured Approach to Advanced Candidate Selection and Treatment Design of Stimulation Treatments
Authors: Nitters Gerrit , Roodhart Leo , Jongma Hans , Yeager Valerie , Buijse Marten , Fulton Dwight , Dahl Jeff , Jantz Eric
Published: December 2007

Because many oilfield workers see matrix treatments of wells as a low-tech operation, they often fail to pay attention to candidate selection and treatment design. This lack of attention may have led to the relatively low success rate of these treatments. A 1997 survey in a major oil company indicated that one out of every three to four jobs fails to produce more oil or gas after the treatment. This failure represents a loss to the company of over $10 million (U.S.), plus a missed extra production capacity of nearly 40,000 BOPD. The probable main cause for this poor performance is the lack of a structured approach to the following: selecting the right candidate wells and the appropriate treatmentdefining and implementing a structured treatment design procedure

To improve the situation, a task force investigated the problem and mapped out a total process, which consists of the following steps: A candidate well is selected by comparing its actual performance against its theoretical potential. Then, the source of poor performance is identified, if applicable. Based on this information, the treatment type can be identified and designed, ultimately resulting in an operational stimulation program.

The task force concluded that individual pieces of design software and some design rules existed for many elements, but they lacked an integrated overall approach. The team decided to create a software package by integrating "fuzzy" rules with appropriate mathematical models to guide field engineers through the individual design steps in a consistent, structured manner. This paper describes various elements of the integrated software package that was designed to meet these needs.
The Fifth SPE Colloquium on Petroleum Engineering Education - An Industry Perspective
Authors: Kazemi H. , Lee W. John , Blasingame Thomas A. , Alman Rex , Bassiouni Zaki , Bowman Charles H. , Eustes Alfred W. , Green Don W. , Heinze Lloyd R. , Horne Roland N. , Judah Janeen , Miller Mark A. , Numbere Daopu T. , Prado Mauricio G. , Tiedemann Herb
Published: December 2007

The Fifth SPE Colloquium on Petroleum Engineering Education (CPEE),, held 23–28 July 2000, was a very successful gathering of educators, technical leaders, engineers, and scientists from academia, industry, and government. The purpose was to address the critical issue of industry-university-government partnership in education, technology development, and technology transfer. The ultimate goal was to identify ways to develop the engineers and technology that the industry will need for the future.

This paper reports the consensus of the Colloquium pertaining to: 1) the industry's current expectations for new petroleum engineering graduates (B.S., M.S., and Ph.D.) and 2) the future of research and development (R&D) activity in academia.

Other subjects such as petroleum engineering education, curricula, technology transfer, and ABET (Accreditation Board for Engineering and Technology) issues are presented in a companion paper.

In the context of this paper, academia refers to the U.S. petroleum engineering schools, and industry means the upstream segment of the U.S. petroleum industry. While this presentation has a U.S. framework, some findings may certainly apply globally elsewhere.
Sand Production Prediction of Weizhou12-1 Oilfield in Beibu Gulf in South China Sea
Authors: Wang Pingshuang , Zhou Jianliang , Li Ming
Published: December 2007

Sand production is a serious problem widely existing in oil/gas production. Most of the China offshore oil field belongs to unconsolidated sand reservoir, in which there exist various degrees of sand production. At present, sand production prediction methods often used in China are Modulus Method, by which a qualitative conclusion can be obtained that weather oil well produced sand or not, but using the method, the critical drawdown pressure without sand could not be gotten. Weizhou 12–1 oilfield is located Beibu Gulf of South China Sea, the rocks of the payzone are situated between unconsolidated and consolidated, The well depth is about 2500m to 3100m. During DST operation for W12–1-2 well and W12–1-3 well, some sands were found in the surface oil /gas separator (taken half volume of the separator). It is difficult to make decision yes or no to sand control.

The authors collected the information of the oilfield (logging data, cores, DST etc.), done rock strength test in various conditions (unconfined strength, tri-axial strength, formation water soak), set a sand production prediction system to predict sand potential of Weizhou 12–1 oilfield, and gave the quantification data for critical differential pressure without sand, suggested the well completion method in final.
Composition Features of Bitumens Taken from the Productive Oil Beds of the Devonian and Carboniferous Deposits of Tatarstan’s Fields
Authors: Ganeeva Yu. M. , Yusupova T. N. , Petrova L. M. , Foss T. R. , Romanov G. V.
Published: December 2007

The complex study of the bitumens of productive oil beds of Devonian and Carboniferous deposits of Tatarstan’s fields have been made.

In hydrocarbon composition of bitumens the absence of alkanes less than C15 both normal and an isoprenoid structure is observed. The higher degree of isoprenoid alkanes contents reduction right up to complete disappearance at broader exchange with environment was found that is indicative of oxidative nature of a bitumens formation. The bitumens composition differs from residual oil one by increased content of asphaltenes. Besides, a process of oil component transformation is accompanied by forming the structures like carbene and carboid types, which depending on conditions of oxidation can be connected with asphaltene particles of bitumen but can fall out as a separate phase on the rocks.

Thus, the complex studies of bitumin-containing rocks and bitumens of productive oil beds shown that the main processes of bitumen formation are oxidation, multiphase filling of deposit and resin-asphaltene components accumulation at break of deposit impermeability. In each specific event the prevailing processes of bitumen formation are characterized.
Discussions of Supplementary Decision Technology of HSE Management in Petroleum Drilling Engineering
Authors: Chen Wanggen , Zhang Yongjian , Zhao Hongzhi
Published: December 2007

Applying modern safety management method such as safety system engineering theory and decision support technology, and combining with the actual problem, we build the HSE management and supplementary decision method on the base of HSE information management by means of the system safety evaluation, index predication and accident model identification technology of petroleum drilling. The paper only discussed the basic thinking, principle and relevant problems.
The Comprehensive Determination Technique and Application of Remaining Oil in Complex Miniature Fault Block Reservoir
Authors: Liu Wei , Zhou Liqin , Wang Shen , Yang Gao
Published: December 2007

The causes of remaining oil in complex miniature fault block reservoir arevery complicated. On the basis of analysis of remaining oil determinationtechnique at home and abroad, this paper presented 14 determination methods in6 categories and formed the technique complex to determinate remaining oil forfavorable oil bearing structure and developed reservoir by combining thedynamic and static characteristics, macro and micro scales, resolved thedifficult problem of interpretation and transverse prediction of internalmicro-fault in complex fracture zone, coning body in strongly water floodedmicro-reservoir, lateral drilling in casing pipe with slim hole andmulti-target in a single well. This paper also determinate the remaining oildistribution in 8 reservoirs including Yaotan, Caoshe, Xi'nanzhuang etc. Aftertesting in Yaotan and Xi'nanzhuang reservoir, 23.34t/d and 21.32t/d oil rateare obtained in assigned remaining oil area and in strongly water floodedmember one section of Dainan formation in Caoshe oilfield. By usingCO2 huff and puff, water production was reduced and oil increased.
An Integrated Approach to Marginal Field Development: Case History from the Gulf of Suez
Authors: Hassan A. , Elshahawi H. , Gad K.
Published: December 2007

The development of marginal oil fields is becoming progressively more important in mature oil provinces. The integrated application of the latest oil field technology has helped to make such development not only technically feasible, but also economically attractive. The Younis field operated by the Gulf of Suez Petroleum Company (GUPCO) is a marginal field made economical through an integrated development strategy that employs cutting edge technology. The success of this strategy represents the culmination of the multi-disciplinary efforts of geologists and geophysicists, reservoir and production specialists, operations and production engineers, as well as the various service companies involved. The technologies applied include the following: Application of 3-D seismic techniques for reservoir delineationInfill drilling of water injectors as well as new producers to improve the oil sweep efficiency.Use of gravel packs in both injectors and producers in order to minimize sand migration.One of the world’s first examples of the successful use of extreme overbalance techniques in high permeability reservoirs for more effective gravel pack placement.The world’s first use of coiled tubing pipelines to feed the field with gas for artificial lift and water for injection.The combined use of reservoir saturation and production logging measurements to monitor water front advancement and thus enable proper management of the water injection project.

Throughout, an integrated approach and a disciplined project plan have been essential for maintaining a cost effective and timely execution. Results have clearly illustrated the success of this approach, leading to a doubling of the oil production rate as well as the proven field reserves. This paper reviews the above mentioned applications and highlights the seamless integration of the efforts of various departments and multidisciplinary teams.
Experimental Evidences for the Mobility of Weak Gel in the Porous Media
Authors: Shen Pingping , Han Dong , Li Wei , Shiyi Yuan
Published: December 2007

The flow behaviors and displacement results of low concentration weak gel (LCWG) formed by polyacrylamide – organic chelate Cr(III) were carefully studies by using a series of sand packs. The results show that the flowing behavior of LCWG in porous media is quite different from that of plugging agent and polymer solution, and demonstrates the flowing capability in certain extent. During the test of the three-layer heterogeneous artificial model, the injection pressure vibrated with the oil production simultaneously. It shows that the flowing gel plugged new breakthrough of brine. It is evident that LCWG could flow with water slowly. The flowing pattern of LCWG could be described by three parameters of the resistance factor, maximum resistance factor and the residual resistance factor. The swept volume could be enlarged and the heterogeneity of internal layers could be modified by the injection LCWG after both water flooding and polymer flooding. The magnitudes of incremental recovery for LCWG injection after water flooding and polymer flooding are 10 and 20% respectively.
Continued and Efficient Development of Cainan Oilfield
Authors: Xingxun Li , Nan Shen , Yong Chen , Wu Zhang
Published: December 2007

Based on automatic advantages and thorough research of Cainan reservoir with advanced techniques, production technique policies and measurements of maintaining production suitable for Cainan reservoir characteristics were applied to two set pay zones of the oilfield, which made the oilfield with low-extra-low permeability keep production stable for eight years by production ratio of 0.3 percent more than the program, and created great economic profit. The average water cut increasing ratio was brought under control, less than 2.1 percent; the degree of keeping formation pressure was more than 80 percent of the original reservoir pressure. It was predicted that the reservoir could be kept production stable until the year 2003 by production ratio determined by the program. At present, accumulative production oil volume of Cainan oilfield is 10 million tons, production operation cost is 80–95¥ RMB per ton, accumulative profit reaches 10 billion ¥ RMB which is more than six times the total investment of the oilfield.
Slag MTC Techniques Slove Cementing Problems in Complex Wells
Authors: Song Mingquan , Wang Wenli , Ma Kaihua
Published: December 2007

Slag MTC is a unique cementing technique that drilling fluid is converted to cement slurry with the addition of blast furnace slag. By controlling slag activating speed and colloid content in MTC slurry, Slag MTC not only has the properties which meet the requirements of normal cementing jobs, but also shows the advantages slurry in rheology, transition time of static gel strength, settlement stability, volume shrinkage and compatibility with drilling fluid. After using slag MTC in 130 wells, we can say this technique not only can get good quality of cement job in normal wells but also is very useful for solving the problems of gas migration in high pressure well and poor quality in small clearance in directional wells and lost circulation in low pressure well. 100% of cement job were successful among these 130 wells.

The authors described the advantages of this technique in solving cement problems of complex wells and analyzed the properties of slag MTC. Three cementing cases in typical wells are presented.
Analysis of Oil Field Economic Performance
Authors: Macary S. M. , A/Razek M. , El-Gohary H.
Published: December 2007

Nowadays, economics control any of decision making and future projection. For the last two decades, energy supply has suffered from a series of oil crises. This makes reservoir and production engineers directing their attention to study the economic performance of oil fields. This was and still accompanied by the need to update reserves and develop producing fields at a fair investment and good revenues The present work investigates the integration of cost data with operational, reservoir and financial information. Engineering and financial groups paid a great effort to unitize both engineering and financial views, regarding the definitions and classification of cost elements. The study deals with the data of one production unit, that is El-Morgan-36 Platform, as it is the greatest complex in The Gulf of Suez. The paper presents a definition for Economic Limit of production rate and a method for its estimation in the light of fixed costs and water oil ratio sensitivities. Historical data of cost and prices are used to predict future performance of both factors considering their interaction, which in conjunction with the production forecast portrays a dynamic value of economic limit forecast. The major advantage of this method of economic analysis performance is that it makes the process of economic limit evaluation to be easier and quick for engineers.

Moreover, the study, for the first time, enables the production report to have cost elements of the production units (wells, platforms, formations, and fields). In addition, the paper presents a prototype example of net cash flow calculations performed for an actual case of East Tanka-A project. The evaluation of workover success is also included.
New Biopolymers for Drilling, Drill-In, Completions, Spacer, and Coil-Tubing Fluids, Part II
Authors: Navarrete R. C. , Seheult J. M. , Coffey M. D.
Published: December 2007

Xanthan gum has been used extensively as a viscosifier in the oil industry for different applications due to its unique rheological properties. In this paper we describe the properties of two previously introduced bio-polymers for use in drilling, drill-in, completions, spacer fluids and coiled tubing applications. The first bio-polymer yields higher viscosities and better temperature stability at lower polymer concentrations than welan and xanthan gum due to its higher molecular weight; this polymer is particularly effective in low salt fluids. The second bio-polymer has improved solubility in high density CaCl2 brines.

Viscosity data over a wide shear rate range in different brine systems is presented comparing the new bio-polymers with xanthan and welan gum at temperatures between 75°F to 330°F. The effect of different types of solids and friction pressure tests in coiled tubing are presented, showing diutan's friction reduction properties.
Paraffin Solvation in the Oilfield
Authors: Barker K. M. , Newberry M. E. , Yin Y. R.
Published: December 2007

Paraffin damage occurs from the reservoir1,2,3,4 to the refinery. This deposition costs the oil companies hundreds of millions of dollars per year in removal costs and much more in lost production. Solvents of many different types are used to try to remove this damage with mixed results. This paper will discuss the various factors involved in the paraffin solvency process: the effect of temperature, the carbon chain length of the n-alkane, the solvent type and application problems. The solvent capacities of commonly used solvents will be compared over a range of temperatures (40ºF to 100ºF) using different chain length n-alkanes or paraffin.