bluuebunny/crossref_metadata_2025_split huggingface dataset:
Redevelopment of a Previously Uneconomic Reservoir from a Mature Oilfield, Offshore South China
Authors: Zhenghe Yan , Xiaofei Gao , Yong Yang , Zhihua Rao , Donghong Luo , Azwar Olivia , Chao Wang , Halomoan Parlindungan Monris , Bisain Amarjit Singh 
Published: March 2015

Abstract
After more than 20 years of intensive production in XiJiang oil field, a sand group that consists of multiple reservoirs with a thin oil column of less than 4 m and with strong bottom water drive has been revisited. Some assessments were made previously, including drilling horizontal wells with average recovery factor or only 2.3%.
In early 2013, new horizontal well drilling was initiated to reassess these reservoirs with a different approach. The objectives were to optimize the standoff between the lateral and the oil/water contact, which is very critical to well performance, by placing the lateral as close as possible to the reservoir top and to evenly regulate the downhole flow across the draining lateral.
The program was successful in reassessing the development reservoirs in the mature oil field that had previously been considered to be uneconomic through a reentry horizontal well drilling program and the implementation of the best practices in operations.
The operational practices included the precise landing and lateral placement of horizontal wells and the use of inflow control devices (ICD) for completion. Logging-while-drilling (LWD) bed-boundary mapping, with the ability to map multiple key boundaries, including fluid contact for precise well placement, was integrated with multifunction formation evaluation LWD, which provides real-time formation evaluation to optimize the ICD design for completion.
Outstanding outcomes have been observed upon the completion of the well: Producing with 1,600 BOPD with 5% water cutAchieving 56% higher cumulative incremental oil than the best previous horizontal wellExceeding the economic level threshold to develop
Comparison of new and the past well performance support the acquisition of the new field data. The successful approach, best practices, and valuable lessons learned provided a breakthrough in developing the previously unexploited reservoir.
First time Utilization of Portable Multiphase Flow Meter for Testing Offshore wells in Saudi Arabia
Authors: Alsalman Ali , Almutairi Ahmed , Alsyed Samih , Kumar Vikash 
Published: March 2015

Abstract
Multiphase flow meters (MPFM) have been used in the oil industry since the late 1990s to perform a rate test and ensure proper allocation from wells. On the same track, the MPFM installation and utilization in Safaniya, the world's largest offshore oilfield, started about a decade ago. Due to logistical constraints and financial priorities, not all platforms were equipped with MPFM. Moreover, Jack-up test barges with separators have been utilized in the field to test platforms without MPFM installation, platforms with faulty meters or with noncommissioned meters.
To expedite testing of non-MPFM equipped platforms and to reduce dependency on jack-up barges, a new concept of portable MPFM testing, with the MPFM equipment mobilized on a boat, was tried in Safaniya offshore field. This also came with the added benefit of testing wells on some platforms where jack-up barges could not visit due to either shallow-water depth or unsuitable seabed for jack-up rig activities.
The Portable MPFM Testing Project had its own operational and technical challenges. The main operational challenges for safe rig-up and rig-down procedures included: positioning the MPFM skid on offshore platforms, proper connection of flow-lines for rate-tests, and safe depressurization of lines before rig down. The technical challenges included: the quality of testing results, calibration of meter between platforms and acquiring accurate PVT data on the spot, and using proper centrifuge with other associated equipment.
This paper addresses in detail the initial hurdles in the above described issues and the measures taken to overcome these challenges. Over one hundred wells were tested utilizing portable meters so far and lessons learned are applied continuously. Testing with portable MPFM will be applied in the future in other Saudi Aramco fields, including both offshore platforms and onshore well-sites.
Well Testing Analysis of Horizontal Open Hole Multistage Fracturing Wells in Tight Gas Condensate Reservoirs in Saudi Arabia to Characterize Production Performance and Fracture Behavior: Case Studies
Authors: Dawood Mahdi Al , Aziz Azly Abdul , Rahim Zillur , Al-Omair Ahmed , Anisur Rahman N.M. 
Published: March 2015

Abstract
Horizontal Open Hole multistage fracturing (OHMSF) completion is the preferred completion to develop the tight and heterogeneous carbonate reservoir. Production data analyses and pressure transient tests are systematically and routinely conducted on these wells to determine the well productivity indices and evaluate key reservoir and fracture parameters. The OHMSF completions have been implemented since 2009 and have showed remarkable results compared to other completions and stimulation strategies such as vertical wells with single or multistage fracturing and open hole multilateral wells with maximum reservoir contacts.
This paper presents the modeling and interpretation of production and actual pressure transient responses of horizontal OHMSF wells that were drilled in both the minimum horizontal stress (σmin) direction and the maximum horizontal stress (σmax) directions to assess the production and fracture behavior. Creating transverse fractures has shown better productivity compared to the longitudinal fractures in terms of production performance, which is corroborated in the paper through pressure transient analyses (PTA) and results from field data. The paper evaluates the impact of the fracture parameters such as fracture half length, conductivity, orientation, and number of fractures on production and pressure behavior. Well testing and production analyses tools are very powerful techniques to assess and compare different types of flow regimes for horizontal OHMSF wells drilled in different azimuth directions. This paper discusses and explains the different derivative shapes captured during well tests and compares these to the simulated and theoretical models. Also, the transmissibility values obtained from the mini falloff (MFO) test following during the fracture injectivity operations are compared with the flow capacity values calculated from the PTA. Challenges impacting pressure transient responses such as high wellbore storage are addressed in the paper and proper planning and use of best practices in the PTA to obtain accurate results are discussed and presented.
Evaluation and Quality Checks to Ensure Reliability and Sustainability of Safaniyah Multiphase Flow Meters (MPFMs)
Authors: Al Muailu Husain A. , Al Yateem K. S. , Al Mutairi A. A. , Kumar Vikash , Al-Ghamdi Ahmed 
Published: March 2015

Abstract
Since the mid-1990s, Multiphase Flow Meters (MPFM) has evolved from a revolutionary new technology into a consolidated solution widely adopted by all the major operators worldwide. This evolution has taken place mainly due to the need for high quality measurements at low operational cost and the capability of enabling remote monitoring with ease. More than 80 MPFMs have been installed in Saudi Aramco's offshore Safaniyah field offshore Saudi Aramco. The utilization of MPFM technology goes back to 2003 thus enabling Saudi Aramco to gather the reliable production data from the field and significant knowledge of operating such equipment1. MPFMs like other devices in the field are prone to failure and therefore are subjected to regular checkups and routine maintenance. Not only the physical equipment but also the data provided by MPFM must be quality checked and calibrated periodically as part of building sound Intelligent Field Infrastructure (IFI). Therefore, to ensure a continuous flow of valid production data from the field to the desktop, several measures of data QA/QC are implemented and will be presented in this paper.
One of these measures was the establishment of a service contract with one of the major MPFM suppliers to service and maintain the integrity of the MPFM software and hardware. The objective of this case study was, therefore, to analyze the main issues related to both data quality and physical checks faced by Saudi Aramco and the service company during the last nine years of MPFM operations in the Safaniyah field. Also to share experiences and lessons learned over such an extended period of time of working with MPFM, especially in an offshore environment dealing with various operating conditions, flow regimes and an artificial lift. In this paper, the effect of field PVT variation over time on MPFM will also be discussed.
Unlock HTHP Unconventional Play in West China by Integrating Cross Domain Expertise
Authors: Zhang Fuxiang , Hao Jun , Peng Jianxin , Liu Hai , Yuan Xuefang , Qiu Kaibin , Zou Guoqing , Dong Jianyi , Judd Tobias 
Published: March 2015

Abstract
Reservoirs in the Tarim Basin located in Western China can exceed 6100m [20,000 feet] TVD and often classified as high- pressure high-temperature (HPHT). These sandstone formations are ultra-deep with presence of natural fractures and temperatures approaching 190°C [375°F] and reservoir pressure ranging between 110 to 125 MPa [16,000 to 18,000 psi]. The development of such resources comes with unique challenges that require a coordinated and integrated approach when drilling, collecting sub-surface data, well completions, and intervention operations. All of these tasks pose unique challenges that are often not encountered in other hydrocarbon basins. Hydraulic fracturing is a critical component to the well completion practice and is obligatory in order to maximize well productivity. This type of reservoir poses serious technical challenges that must overcome and account for the geological, geomechanical, and petrophysical interpretation. The integrated approach towards understanding the reservoir combined with the use of a novel fracture diversion technology was undertaken to ensure the maximum surface area contacted by the fracture with the reservoir and wellbore. The hydraulic fracturing design process involved the identification of intervals for multiple perforation clusters across the 200m [650 feet] reservoir section and then executing multiple stage stimulation treatments in which a fluid and proppant schedule would be pumped followed by the application of this dynamic diversion technology.
This paper will discuss this case history from a workflow perspective, introduction of this fracturing technology while using a weighted fracturing fluid with a specific gravity of 1.3, the treatment observations identified through real-time microseismic, and discuss how the better reservoir understanding enabled an improved completion strategy. The ten wells with this approach are best in class from a production standpoint when compared to the three tier reservoir potential ranking approach. Finally, the lessons learned from the first phase of this project will help guided future development activities.
Conditioning Pre-existing Old Vertical Wells to Stimulate and Test Vaca Muerta Shale Productivity through the Application of Pinpoint Completion Techniques
Authors: Forni Pablo , Bonapace Juan C. , Kovalenko Federico , Garcia Mariano N. , Sorenson Federico 
Published: March 2015

Abstract
One of the most promising targets for resource rock stimulation in South America is the Vaca Muerta (VM) shale in western Argentina. Because of high initial costs and also the typical reservoir information that must be acquired, it is common practice for operators to begin exploration projects with vertical wells. This is also the case for unconventional reservoirs, so initial vertical wells are used for reservoir characterization/initial comprehension and also to test the productivity of the different intervals.
Within the Neuquina basin, existing vertical wells were typically drilled to produce reservoirs below the VM source rock. Presently, with these reservoirs depleted in many areas, existing wells are often a great opportunity to investigate this upper unconventional target. Unfortunately, most of these wells are not viable candidates because they were designed to be completed through tubing. Casings and wellheads, in general, are not sufficiently strong to support pressure requirements for fracture stimulation of unconventional reservoirs.
This paper discusses the preparation of a well originally drilled in 1974 to allow for the new objective of hydraulic fracturing the VM shale to test the productivity of its different intervals. A coiled tubing (CT) assisted pinpoint completion technique (hydrajet perforating and annulus fracturing) was used to independently stimulate small intervals. To help assure that most of the reservoir was indeed stimulated, 12 single-zone fracturing stages were used for 130 meters of gross interval.
To isolate the upper (weakest) section of the wellbore, a 4 1/2-in. P-110 casing and swellable packer were installed.
Evaluation of Fracturing Fluid for Extreme Temperature Applications
Authors: Prakash Chetan , Achalpurkar Manoj , Uppuluri Ramesh 
Published: March 2015

Abstract
Hydraulic fracturing has remained a fundamental technique for stimulation of oil and gas reservoirs for enhanced or economic recovery of hydrocarbons from tight formations for more than 60 years. Transporting proppant downhole without any interruption and then to obtain maximum recovery of fracturing fluids are two important criteria for successful hydraulic fracturing. To achieve such objectives, the fracturing fluid should demonstrate good viscosity and complete cleanup of gelling agents. Because wells are exploited at both shallow and great depths in environments of moderate to very high temperatures and pressures, fracturing fluid selection is fundamental. Fracturing fluids prepared by crosslinking guar, guar derivatives, and other naturally occurring polymers with borate or metal crosslinkers often exhibit instability at very high temperatures. The primary reason for instability of the fracturing fluid is because strength of the bonds between the polymer chain and crosslinker decreases sharply in addition to breakdown of the glycosidic bonds between monomer units of the polymer chain beyond 375°F. Additionally, metal crosslinked bonds are prone to shear degradation, creating doubt for a successful stimulation treatment in high-temperature extended-reach wells.
To address these issues, a synthetic gelling-agent-based fracturing fluid that can work at temperatures greater than 400°F was developed. The gelling agent is a terpolymer, which can be crosslinked with a zirconium-based crosslinker. This paper discusses evaluation and performance of an extreme temperature fracturing fluid. This fracturing fluid system has sufficient proppant carrying viscosity and provides efficient post-treatment cleanup using delayed oxidized breaker. Analysis of fluid viscosity stability and delayed oxidizing breaker usage is presented in addition to performance parameters such as regained permeability and fluid loss. The study illustrates performance of the synthetic gelling-agent-based fracturing fluid at temperatures ranging from 380 to 440°F.
Successful Water Conformance Control in Horizontal Wells Using ICD Completions- A Case History Spanning Over 7 Years from Greater Burgan Field in Kuwait
Authors: Gilani Syed Zubair , Gazi Naz H. , Kotecha Rohitkumar , Shastri Mukesh Chandra , Al-Sabea Salem , Al-Humoud Jamal , Ali Badria A 
Published: March 2015

Abstract
Unwanted water production is a major challenge in the horizontal wells in the Greater Burgan field in Kuwait. The long lateral sections and the presence of heterogeneity lead to uneven sweep of hydrocarbons. Greater Burgan has over 60 horizontal wells to date. Initially they produced dry oil and up to the expectation but soon the water cut increased in a number of wells and avoiding water break through became a major challenge.
Burgan sandstone is a highly productive reservoir and the permeability variation is huge from less than a Darcy to a few Darcy. Thus, the horizontal wells have uneven flow profile and subsequent coning and cresting effects resulting in bypassed oil and poor recovery.
To have a better down-hole water management in horizontal wells a number of options from chemical water shut-off and isolating the toe side using packers to use of straddle packers in the middle and heel side of the horizontal section were tried. However, the use of Inflow Control Device-ICD proved to be the best option to restrict and slow down and contain the water production by creating additional pressure drop and achieve better sweep efficiency.
The first ICD completion in the Greater Burgan field and in KOC was implemented in a sidetrack well in 2007. To date the well is flowing with 45% water cut which is almost constant from the beginning for 7 years now. It resulted in a net gain of 2400BOPD from this well.
This paper will describe this case history, how the system was designed, completed, and monitored, and the successful results achieved for over 7 years. This successful use of ICDs for water conformance lead to more applications in Kuwait and will give a good understanding for the future use in other areas.
Production Logging Interpretation Challenges in Evaluating Highly Deviated Wells with Advanced ICD Completions
Authors: Espinoza Irina Baca , Vicario Roberto , Affandi Imam 
Published: March 2015

Abstract
In the last decade, more complex and efficient way to complete the wells has been used to maximize and optimize the production in highly deviated/horizontal-reach wells. This requires adjustments to the production logging (PL) interpretation methodology.
This paper demonstrates the complexity of PLT interpretation in highly deviated wells completed with inflow control devices (ICD) and openhole packers in carbonate formations. The addressed issues and solutions include downhole calibrations, holdup and velocity stream determination for different fluids in the production tubing and accounting for the effect of wellbore inclination and inflow distribution from several fluid entries per single isolated zone. Production logging is performed using standard and advanced tools, such as multiple array modules and pulsed-neutron tools.
The ICD pre-installation design is strongly based on the availability of a permeability profile, which is usually derived by static data logging interpretation. Consequently, the second objective of this paper is to compare the initial permeability profile with the permeability profile derived by interpretation of dynamic data such as PL.
The results from production logging analysis demonstrate that the standard method of PL interpretation could be applied for advanced ICD completion evaluation by taking into consideration several factors such as calibration, well deviation and associated holdup, flow regime and zonal inflow distribution for multi-ICD inlets. The applicable software used for comparison of pre-design completion static-derived productivity index (PI) is contrasted with dynamic-derived PI from production logging tool (PLT). The pressure regime in the wellbore and annular pressures behind ICDs were used as additional input for better understanding the fluid flowing nature and investigation of the productivity index.
The confirmed continuous permeability profile enables grid refining in a reservoir simulation study and better planning of the well production performance. The technique and solutions described in this paper can be widely used to evaluate and improve carbonate reservoir characterization for every deviated well completed with inflow control devices.
Formation Testing While Drilling Enables Successful Pressure Data Acquisition in Depleted Reservoir Zone Not Previously Possible with Wireline Logging in Kuwait: A Success Story
Authors: Al-Khaldy Meshal D. , Safar Ahmad , Kumar Sanjeev , De Santanu , Dutta Abhijit , Makki Ahmed , Al-Shammari Altaf , Samie Mohamed Abdel , Ibrahim Ahmed A. , Warraky Mohamed , Abdulkarim Anar 
Published: March 2015

Abstract
Formation testing while drilling (FTWD) proved to be of great value to the asset team at Kuwait Oil Company (KOC) while recently drilling a deep, deviated well to target the Zubair sands.
The deviated 8-1/2-in. hole section of the well had been planned to cut through more than 1,100 ft of true vertical thickness containing multiple reservoir units with varying pressures, lithologies, and formation characteristics, which posed a great risk for drilling operations and required the use of relatively high-density mud to maintain wellbore stability. The presence of highly depleted reservoir zones in this mature reservoir resulted in a challenging pressure overbalance in excess of 4,800 psi.
Attempts to measure formation pressure in previous vertical offset wells in the same depleted zone in the same field/environment using wireline formation testers yielded either unsuccessful or erroneous results, indicating a tight formation, which conflicted with previous production and coring data available that suggested high-permeability sands were present. The high overbalance was suspected to be the primary cause of formation damage and blockage resulting from solids content in the drilling fluid and longer exposure time. KOC has historically opted for taking pressure points in wipe mode rather than dynamically while drilling in open holes containing unstable Zubair shales. Moreover, a large number of planned pressure points with the drilling assembly cutting across various sand zones posed several challenges.
The asset team had plans to exploit such depleted zones through future horizontal drilling; however, an up-to-date pressure measurement was required to assess feasibility.
This paper discusses the planning, design, and execution of this well. It also focuses on the use of the FTWD solution alongside other logging-while-drilling (LWD) and rotary steerable assemblies to overcome the drilling challenges and successfully follow the planned data-acquisition program to optimize the completion and production strategy and discusses how the solution affected the decision making for future wells.