bluuebunny/crossref_metadata_2025_split huggingface dataset:
Extreme Overbalance Perforating and One-Trip Perforate and Gravel Pack-Combination of Two Techniques for Successful High Rate Gas Well Completions in the Ha'py Field
Authors: Vickery E. Harold , Hill Leo E. , Forgenie Victor , McCollin Roger , Fahmy Helmy , Butler Carl H. , Mohamed Omar Y. 
Published: December 2007

Abstract
The Extreme Overbalanced Perforating (EOB) technique has been successfully applied in a variety of locations around the world both in ‘hard rock’ and ‘soft rock’ formations. In certain applications, it offers definite advantages over other perforating techniques. One-Trip Perforating and Gravel Pack technology also has been successfully applied at various locations with definite advantages over other ‘soft rock’ cased hole completion techniques. Prior to the completion of three wells in the Ha'py field, these two technologies had never been applied concurrently.
This paper describes the teamwork that was required between the operating company and the service providers to properly combine these methods and ensure their successful application in the field. The authors outline some of the obstacles encountered and describe how the tools and procedures were designed for success.
During the three well completions in the Ha'py field, some problems were encountered that required modifications to operations. The lessons learned from these problems and how they were applied to subsequent operations are also addressed.
Simultaneous Gravel Packing and Filtercake Cleanup with Shunt Tubes in Open-Hole Completions: A Case History from the Gulf of Mexico
Authors: Godwin Keith , Gadiyar Bala , Riordan Hal 
Published: December 2007

Abstract
The cleanup of reservoir drill-in fluid filtercake presents a significant challenge in long open-hole gravel-packed completions. In an effort to prevent leak-off into the formation and ensure complete interval packing, it is advantageous to leave the filtercake in place during gravel-pack operations. A post gravel-pack breaker treatment is then performed to remove the filtercake. This treatment typically consists of a coiled tubing operation in which chemical breakers (enzymes or oxidizers) and/or acid systems are pumped to attack the polymeric and CaCO3 components of the filtercake. Acid treatments or two-stage enzyme /oxidizer soaks followed by acid can be ineffective in providing uniform cake removal and can result in substantial associated cleanup costs. Cake cleanup while gravel packing has recently been proposed to reduce an otherwise two or three-stage process to a single stage, thus eliminating the need for coiled tubing and ensuring breaker contact with the filtercake throughout the entire interval.
In this paper a case history from the Gulf of Mexico for drilling and completing a horizontal open-hole well utilizing simultaneous gravel-packing and cake-cleanup with the alternate path technique is presented. The open-hole section was 277 feet deviated from 85° to 90°. Bottom-hole static temperature was 128°F. The producing sand was normally pressured. The drill-in fluid and gravel-pack carrier / filtercake removal fluid selection was based upon extensive laboratory testing which consisted of clean-up, compatibility, and sand suspension capability tests. A reservoir drill-in fluid comprised of a brine, starch, a biopolymer, and sized calcium carbonate was chosen for the project. A viscoelastic surfactant fluid in a chelating-agent solution containing an enzyme breaker to simultaneously attack both the starch and the CaCO3 components of the filtercake was identified as the best carrier fluid for the gravel pack. Laboratory test results, field procedures, and the production results are discussed in detail along with the decision process that resulted in the selected drill and completion plan.
An Integrated Approach to Evaluation of Horizontal Completions in Panna Field: A Coning Dominated Heterogeneous Limestone Reservoir
Authors: Kak Suhail , Malik Sanjeev , Choudhuri Biswajit 
Published: December 2007

Abstract
The Panna field is a heterogeneous limestone reservoir consisting of a thin oil column overlain by a gas cap and underlain by a water column. The reservoir is coning dominated and the wells show a marked increase in Gas Oil Ratio (GOR) and water cut very early in the production history. Horizontal wells were drilled to minimize drawdown, and hence coning, and maximize recovery. The initial horizontals had openhole completions and displayed a peculiar inflow performance curve that was concave upwards and almost flat at the higher rates. This was thought to be caused by the formation of water sumps at low rates, due to the undulating profile of the drainhole & the low fluid velocities, which resulted in a non-uniform flow contribution along the horizontal. Subsequent wells were completed with a centralized, selectively perforated tubing (tailpipe) installed in the drainhole and it was thought that this would result in a uniform flow contribution along the entire horizontal section and correct the inflow performance curve shape. Analysis of pressure data from the tailpipe wells showed that the tailpipe caused progressively higher drawdown at high rates. However, the flow distribution along the drainhole could not be determined from pressure data alone. A production logging campaign utilizing tractor as the conveyance system had to be aborted due to a) limited coverage of the horizontal section by the tractor and b) operational problems resulting in fishing of the tractor in one of the wells. This campaign was expected to provide an insight into the flow process in the two completions and determine the most optimum one.
This case study presents the performance of the various horizontal completions in existence in the field and integrates production and bottom-hole pressure data to explain them.
The Carbon/Oxygen Log Measurement
Authors: Wichmann P.A. , Hopkinson E.C. , McWhirter V.C. 
Published: December 2007

1978 Rocky Mountain Regional Cody Wyoming May 17–19, 1978

Abstract
A new pulsed neutron logging technique has been developed to unambiguously identify the presence of the element carbon. The Carbon/Oxygen Log is currently available on a limited commercial basis in North America and has been tested under a wide variety of field conditions.
This paper covers the theory of the log's response and shows examples of what is available in the way of taped output. The basics of interpretation by a simplified pattern recognition technique are reviewed along with test pit measurements and verified field response. pit measurements and verified field response

Introduction
During the past three years, a Carbon/Oxygen logging device has been commercially available and has been used to survey several hundred wells. Despite the fact that a great many of these applications have been made as a "last resort" when definitive answers could not be derived from other more conventional logging methods, the device has scored a very high success ratio in predicting the type of fluid ultimately produced. Also complicating these initial efforts is the fact that development and improvement of the instrumentation has been continuous over this period of time and even now, a significant advance is on the verge of commercial introduction.
The Dresser Atlas Carbon/Oxygen Log is made possible by an electro-mechanical device that can be pulsed in extremely short, concentrated bursts of 14 Mev neutrons and a detector system that can selectively discriminate and count the high energy gamma rays that result from the inelastic collisions of these neutrons with the atoms of carbon and oxygen. Figure 1 schematically reviews the source and time frame of neutron bombardment induced gamma radiation. Note that the inelastic or prompt gamma rays exist only while the very high energy neutron source is on and for a very few microseconds following the cessation of the pulse. From this period of time until the neutron source is reactivated, only gamma rays of thermal neutron capture, and to a lesser degree, activation gamma rays, are present. This is an extremely important point, as the 4.43 Mev inelastic carbon gamma ray is the only unambiguous nuclear indicator of that element in nature.
Successful Gas Shut Off Using Latest Gel Technology In An Indian Offshore Carbonate Field — A Case Study
Authors: Sengupta T. K. , Singh Rudal , Avtar Ram , Singh Kharak 
Published: December 2007

Abstract
The offshore-A oil field is located in the Arabian Sea to the west of Mumbai India & is operated by ONGC under Asset based management system. The field is a saturated reservoir with three small gas caps & is under production with pressure maintenance by peripheral water injection. Some of the wells falling near to the gas cap produce with high GOR due to gas coning or cusping. Several efforts made to control the high gas production by conventional cement squeeze technique did not produce any result. As a result the wells were either closed or under production sub-optimally with a low choke size.
The low recovery from the area due to closure of the high GOR wells & unsuccessful attempt of cement squeeze jobs for Gas shut off warranted ONGC to search for new technology to control the high gas production with a deep penetration new gel technology.
Accordingly the gas control jobs were carried out in two wells after an extensive study on reservoir characteristics, selecting best candidate wells & right type of polymer gel, involving laboratory studies to see the compatibility of the gel with the core & formation fluids and using proper gel placement technique. This integrated approach with a multidisciplinary team effort was adopted for the first time under the asset based management system.
The post treatment production data showed significant reduction in total gas production along with substantial increase in oil production which indicates that the gas production from the gas cap has been blocked successfully by this treatment.
The paper deals in detail the integrated team approach adopted in the Asset team for a reservoir focussed conformance solution to improve the recovery which led to a success and has opened up a new era in the gel technology for gas shut off in carbonate reservoirs in Indian offshore fields.
A Numerical Study To Evaluate The Use Of WAG As An EOR Method For Oil Production Improvement At B.Kozluca Field, Turkey
Authors: Cobanoglu Mustafa 
Published: December 2007

AbstractB.Kozluca Field with an OOIP of 138 MMSTB has been producing for more than 16 years. Main producing formation is the carbonate Alt Sinan. Oil gravity is 12.6 °API with a very high viscosity of 500 cp at reservoir conditions. Production mechanism is rock and fluid expansion with a very weak bottom water drive. By the year 2001, the cumulative oil and water production are 3,836,551 stb and 539,059 stb respectively and daily oil production is 570 stb/day with 20 % WC.In 2000, in order to increase the oil recovery, a re-evaluation and reservoir management study was started. This study was initialized by screening the applicable EOR methods. Since there is a CO2 reservoir at Camurlu Field, which is about 10 km from the B.Kozluca field, study was focused on the CO2 injection. Then, a full field simulation and reservoir characterization study was performed. Firstly, a numerical model was used to predict the oil production by current production scenario and then this model was used to make a sensitivity study to determine a certain CO2 injection pattern, number of the injection wells and the optimum injection rate. Although the initial predictions for different immiscible CO2 injection scenarios give very limited incremental oil due to the very adverse mobility ratio between oil and CO2, this application accelerates the oil production. Then, many different Water Alternating Gas (WAG) scenarios were studied and the results showed that WAG will be better than only CO2 injection. In order to find the optimum injection period many scenarios were studied and 60 days of CO2 injection followed by 30 days of water injection scenario was chosen as the best case. Meanwhile, a parallel study was initiated for the design of the surface facilities and well heads for injection wells of B.Kozluca field, a processing facility for CO2 and produced water at B.Kozluca field and CO2 production and treatment facilities at Camurlu field.At the end of the integrated reservoir management study, by applying the WAG technique as an EOR method, it was predicted that more than 7 MMSTB incremental oil will be produced with $ 4.25 MM capital investment for surface facilities, additional perforations, pipe line construction and conversion of production wells to injection wells. With this investment, more than $ 20 MM profit will be gained. Pipeline construction between Camurlu and B.Kozluca field has been already started and Camurlu field surface facilities were evaluated and was found to be sufficient for CO2 production and treatment. Other surface facility constructions are being planned for the coming months.
New Technique to Recover By-passed Reserves Above Packer Reduces the Completion Cost and Maximizes the Well Production in ONWJ Field, Indonesia
Authors: Susilo Yoliandri , Wibowo Wahju , Rich David , Priyandoko Pajang 
Published: December 2007

Abstract
This paper will describe the successful application of cement packers in Offshore Northwest Java Sea (ONWJ) field to recover by-passed reserves that are located above the production packer. Previously, conventional completion techniques required a workover to re-complete these new zones. However, due to their marginal reserves or the well still has good production from existing zones (ex: in dual completion case where long string is still a good producer while short string is already shut-in), a workover is not a good option to recover these by-passed zones. A new treatment technique in ONWJ field, Indonesia, has been developed to re-complete and treat these zones that are located above the production packer without pulling out completion strings. Isolation of potential zones is accomplished by cementing in the tubing-casing annulus above the production packer. The cement above the zone replaces the production packer and conventional perforating is then used to complete the well.
The advantages of this technique are: inexpensive (no rig required), no need to wait for the well to achieve economic limit rates before recovering the zones, and - most importantly - it still allows access into the lower completions. On the other hand, the disadvantages of this technique are: less gun penetration (has to penetrate tubing-cement-casing-cement-formation), and workover/sidetracking below packer is difficult to carry out once the packer has been covered by cement.
To date, a total of 7 wells have been reactivated using this technique to recover the zones/reserves. The jobs have been done successfully in both single and dual completions. The average cost was only 20%-60% of conventional workover jobs and savings of up to US$ 400,000 have been achieved. The production results have also been encouraging. These successful results have brought new opportunities for reactivating many more shut-in wells with by-passed reserves that are economically marginal.
PDC Bits and Rotary Steerable Tools - Functional Challenges, Stabilization Requirements and the Establishment of Operational Compatibility
Authors: Mensa-Wilmot Graham , Stacey Brian 
Published: December 2007

Abstract
The introduction of rotary steerable tools1,2 (RST) has drastically changed how the drilling industry plans and executes directional drilling projects. These tools address most of the technical and operational limitations, which previously hindered directional drilling efficiency. With RSTs, changes to wellbore trajectory are made while the drill string is in continuous rotation. This advantage improves wellbore quality, hole cleaning and Rate of Penetration (ROP). It also reduces well bore tortuosity, torque and drag, and eliminates the harmful effects of "negative weight on bit", especially on extended reach3 (ERD) programs.
The benefits listed above can only be achieved if RSTs are used with appropriate bits4,5,6. The development and/or selection of the "right bit type" for an RST application is "not as simple as perceived". This is due to the numerous technical issues - functional challenges, stabilization requirements and operational compatibility - that have to be addressed. To achieve technical and economic success, bits used with RSTs must also address expected formation drillability issues7, in terms of their ROP and durability.
PDC bits exhibit most of the characteristics needed to establish efficient partnerships with RSTs, especially their structural reliability and ROP potential. These attributes are further enhanced by the "absence of slide mode drilling", due to the continuous rotation of the drill string.
This paper will characterize the technical issues associated with the PDC/RST combination, and show how "appropriate PDC bits" address them. It will draw distinctions between bit aggressiveness (BA) and bit instability (BI), and demonstrate how these parameters are affected by well profile specificity and dog-leg (DLS) requirements. In addition, it will identify and evaluate the requirements needed to ensure operational effectiveness on PDC/RST operations. Several field examples will also be discussed.
Multi-Lateral Level 3 and 4 in PDO
Authors: Al-Hady Abdullah 
Published: December 2007

Abstract
ML technology was started in PDO since 1994 where over 240 ML have been drilled in PDO majority of them are level 2. The increasing complexity of well architecture demands more complex ML systems. Many system available in the market are not mature yet and the other do not meet the specific requirement of PDO. As it is known the main drives for this technology is a reduction in UTC by combining wells (One surface casing, one X-mass tree, and one completion) and reduce number of locations hence surface facilities as the pipe lines and headers. PDO activities with ML can be divided into three different applications. Northern fields where there is no hole instability or sand production problem therefore level 2 is of great success. As an example, in Saih Rawl wells the 6 to 8 producing laterals of level 2 from the same backbone is a routine construction. However, in the southern carbonate fields the hole instability and sand production problems exist. To avoid the sand production problem the lateral should be lined up by WWS or PDL, which required level 3 junction. The present of highly unstable shale at the cap rock add more complicity to the system by requiring a high strength junction for ML system. The third application of the ML technology is in deep stringer oil wells and gas wells where a level 6 system could be applied in the future where high pressure is required due to the reservoir high pressure. This article will brief in the experience we have with different ML systems of level 3 and how this drive us for the level 4 MX-select from Smith Red Baron which is initial design to meet our requirement in Amin field. Also this article will show how to go through sand production and shale ingress through the junction where a cemented junction is not appropriated (Flanged Hook Hanger) and the learning points from the first trial.
Isolation of a Horizontal Hole Section in an Openhole Well Using a NonDamaging Temporary Gel Plug to Facilitate Hydrocarbon Production from the Remaining Lateral Section - A Case History from Kuwait
Authors: Khater Mohammed R. , Uddin Shahab , Al-Rubaiyea Jamal A. , Rai Ashish R. , Gazi Naz 
Published: December 2007

Abstract
This paper describes the application of a nondamaging temporary gel system to isolate a part of a horizontal section in an openhole well. The purpose of this application was to provide a cost effective method of isolating a high water-saturated zone of the extended lateral to facilitate the production of hydrocarbon from the rest of the open hole.
The candidate well (R-91) selected for this application was the first extended lateral horizontal well (3000-ft lateral section) drilled as a producer. The well was to be converted to an injector at a later time.
Logging while drilling (LWD) was performed during the drilling phase of this well, and a low-resistivity section was identified along the horizontal lateral. On completion of the drilling, a well test was performed, indicating a high water cut. It was suspected that this water was being produced from this low resistivity section along the lateral hole.
An economical method for confirming and isolating the source of this water influx was needed. Since this was a low-pressure well, an electric submersible pump (ESP) for production had been used. Since low-pressure wells were the norm for this field, ESP completions were commonplace. Different techniques, including use of drillpipe conveyed or coiled-tubing-conveyed production logging tool (PLT) were also considered.
The nondamaging gel plug placed across the low resistivity section of open hole with coiled-tubing allowed the operator to identify and confirm the source of water. The gel plug formed a barrier across this zone, thereby restricting and reducing the water influx.
Presence of a natural fracture was also identified during the drilling phase, and hence, communication between the low-resistivity interval with the oil zone towards the heel of the lateral section was confirmed. Due to non-availability of certain logging tools at the time of requirement along with high costs of using such tools, the proposed gel technique was used as an alternative option. Being a non-damaging pill with greater than 99% regained permeability after cleanup, the well could safely be isolated with this technique. The pill would be dissolved with acid at a later stage when required.
The procedures and the placement techniques of using two-inch coiled tubing and subsequent test results provided insight into the success and the uncertainties involved.
The post-job analysis of results allowed further optimization of these processes, which would facilitate similar applications in the future.
The operator's objective of drilling this well to initially produce as much oil as possible, and then, at a later stage to convert it into an injector to improve the sweep efficiency in the area was achieved as a result of the application of this technique.
Application of Dual Lateral Wells in A Heavy Crude Oil Reservoir
Authors: Centeno A , Barrios J , Arnone M , Lopez J , Gonzalez M , Ramos D 
Published: December 2007

Abstract
This paper presents the PDVSA experience of multilateral wells planning and construction in a heavy crude oil reservoir. In the planning phase, multilateral technology shown to improve the project economics, based on the construction of 12 multilateral wells. Geology, drilling, completion, and workover aspects were evaluated for selecting the most appropriate junction level. Levels 3 and 4 were fully compared. Level 4 junction was selected after the analysis. So far, PDVSA has constructed 9 MLT wells in Bare field. The production results were as planned and the final economics of the project was better than the estimated values. This paper also presents the learned lessons during well operations and concludes that multilateral technology constitutes an economic alternative for the exploitation of this field. Also, this experience contributed to shape the process required for adapting and transferring new technologies in PDVSA drilling operations.