bluuebunny/crossref_metadata_2025_split huggingface dataset:
Application of Pressure-Monitoring Data in Land-Based Unconventionals
Authors: Marcuccio Suzi , Flygare James , Konopczynski Michael 
Published: October 2015

Abstract
The acquisition of accurate downhole pressure measurements from land-based unconventional wells can enable analysis of pressure data that can be used to help optimize and reduce the cost of fracture treatments and improve overall well productivity. The pressure data for the analysis are obtained from downhole electronic gauges in both the target well and in the surrounding observation/monitoring wells. The objective of this paper is to demonstrate the value monitoring this downhole pressure data can provide throughout the life of land-based unconventional wells. The paper also describes the selection of the equipment, the steps necessary for its successful installation, project commissioning, and acquisition of reliable data throughout the life of the well.
Historically, operators have experienced less-than-desirable success rates for long-term downhole pressure monitoring, especially in multizone, openhole, horizontal wells. This paper discusses how the success rate of these installations has been significantly improved by the implementation of a program with a well-defined series of steps that includes detailed planning (completing the well on paper exercise), onsite function testing of equipment prior to installation, and stringent attention to job execution detail. This program is based on the fact that adoption of the proper selection criteria for the application is critical to selection of the proper type of monitoring equipment and to the operational and economic success of these pressure-monitoring projects.
Production Excellence Opportunities Portfolio Management System: Key in Mature Field Rehabilitation
Authors: Ruslan M. 
Published: October 2015

Abstract
This integrated management system is design to efficiently manage and optimize the production excellence opportunities portfolio especially in mature field where higher risk presence technically and economically. Project management, LEAN process, lesson learnt and best practices were incorporated in developing the standardized workflow. The portfolio optimization model provides comprehensives technical and economical evaluation.
The technical success probability sub-model incorporates the technical KPIs and the project criticality index to generate project level probability. At this level, due to lack of local experience, the outcome can be either optimistic or pessimistic. To prevent this and recognizing the similar technology has been utilized elsewhere to solve similar problem, the industry track record can be combine with local perception via Bayes' Theorem to generate more realistic probability. The potential way forward is to incorporate the sub-model with case based reasoning and Bayes network for a more robust decision and evaluation.
The economic sub-model combined with project schedule incorporates probabilistic assumption to the benefit for each technology, hydrocarbon price, cost and time. The portfolio optimization risk-gain model incorporated both the forecast results from technical and economical sub-models to optimize the new technology portfolio. The model will run 1000 iterations to achieve the objective by maximizing the P50 NPV (net present value) of the project but within the predefined constrained and acceptable risk. The optimization results will be further undergo multidisciplinary peer review prior continuing the standardize workflow.
The management system is currently used in mature field project in North Sea to efficiently identify, manage, optimized the opportunities portfolio, and has demonstrated good execution and success cases.
Major Incidents Prevention and Sharing Lessons Learnt in Oil Field
Authors: Al-Shatti Ahmad , Al-Rakdan Abdulwahab , Al-Khaldy Ali 
Published: October 2015

Abstract
During the exploration and production of oil and gas resources in Kuwait Oil Company, a wide range of risks and dangers are present frequently, which have the potential to result in a major incident.
This paper describes a case study on sharing vital lesson leant from major incidents (work related/ Non-work related) that occurred in recent past. All these incident have thoroughly been investigated and intricate underlying causes and root causes of these incidents been identified. A lot of new lessons from these incidents were identified which are very vital for drilling industry to look upon and learn from these in order to avoid these learning from own experiences on the cost of loss of life/property. Various relevant corrective actions have been described in this paper in order to prevent the occurrence of such incidents in future.
The outcome from this paper is intended to improve the competency of the employees and increase their awareness of the sake of incidents prevention. Kuwait Oil Company has focused on reducing the probability of similar incidents occurring in the future by adopting generative culture in sharing lessons learnt among all employees and conducting various significant initiatives for all HSE aspects. Other Drilling Industry in the region may also be befitted by adopting the outcome of this presentation being in similar nature of work environment.
Factors Affecting Delay of Upstream Oil and Gas Development Projects in Indonesia: Case Study 2012 - 2013
Authors: Simanjuntak Josia T. , Mahendrawan Anggono 
Published: October 2015

Abstract
It is widely accepted that a project is successful when it is finished on time but unfortunately, due to many reasons, in Indonesia, a large number of upstream oil and gas projects failed to meet their original contract time. The success of the delivery of upstream oil and gas projects in particular becomes pivotal as oil and gas production steadily declines each year, and Indonesia's economy and revenue are highly dependent on the upstream oil and gas sector. For example in 2012, 15 projects with the combined maximum throughput capacity of 1,062 MMscfd and 23,060 bopd were initially expected to go on stream. However due to a number of reasons, 12 out of 15 projects were delivered with the combined maximum capacity throughput of 430 MMscfd and 5,600 bopd only.
As mandated by the government, the Special Task Force for Upstream Oil and Gas Business Activities in the Republic of Indonesia (known as SKK Migas) is responsible for developing upstream oil and gas projects as part of its main function in terms of maximizing national oil and gas production. This paper presents our experience, as a government agency, in managing all upstream oil and gas development projects in Indonesia. This paper also reviews the major project and construction management challenges experienced in Indonesia.
All information and data were acquired and gathered throughout a series of intensive monitoring with all Production Sharing Contractors in Indonesia: meetings, discussions, site visits and written reports. All this information was further analyzed and categorized into several main factors that affect the delay of oil and gas development projects based on original Plan of Development and Engineering, Procurement, Construction and Installation contracts. The findings show that the main critical factors that cause delays in Indonesia are contractor performance, logistics, government approval and permit, societal, environmental and commercial issues.
In addition, this paper also explores and provides some recommendations to reduce the impact of delays on oil and gas projects in Indonesia.
Production Optimisation With Zero Gas Venting Through Multiphase Booster Pump and Well Selection
Authors: Maryunani S. , Ranggun R. A. , Johari E. , Ting P. E. , Raislar G. M. , Gajet D. A. 
Published: October 2015

Abstract
TM Platform is a mature oil producing facility located in East Malaysia. It has been producing since 1979. Being an aging field, production with higher gas/oil ratio (GOR) and wider pressure range at remote platform which is flowing into single pipeline to the processing platform, encountered bottlenecking which restricts the flow from lower pressure wells. This paper outlines the concept of technology and operational intervention to minimise surface bottlenecking at one of TM remote platforms, TM-X.
As an effort to boost production from lower pressure (LP) wells at TM-X, a multiphase booster pump (MBP) was commissioned. It was designed to create low suction pressure to enable maximum drawdown from the wells. Selected LP wells were diverted into a dedicated line header, flown into the multiphase pump, and discharged into the main line header to commingle with the higher pressure (HP) wells. Further optimisation of pump capacity was achieved by lowering down the gas throughput. This is done by using routine well testing to select optimum well candidates with lower totat output gas (formation gas plus injected gas) and flowing tubing head pressure (FTHP).
Currently, MBP with optimum well selection is enabling oil gain of approximately 1500–2000 BOPD. Multiphase booster pumps (MBP) is a gas engine driven, plunger type pump. Some of the low FTHP wells which were unable to flow because of backpressure from the higher pressure wells in the pipeline are now able to flow via MBP. MBP is not a common equipment and has never been installed at any offshore location in Malaysia before. Therefore, operating and maintaining it was challenging. Operational intervention such as increasing frontline spares, improving operator competency, and daily parameter logging played a crucial role in ensuring the optimum performance of MBP.
This booster pump and optimisation process can be further replicated at other oil platforms to increase the production, especially in a remote platform which wells have higher GOR or formation gas rate and lower FTHP, but no dedicated pipeline and infrastructure to flow the crude according to its pressure setting range for each higher and lower pressure wells, respectively.
MBP with its nature as a multiphase pump is suitable for remote platform with unmanned philosophy at which continuous local gas venting or emission shall be kept to minimum. With complete unit shutdown system tied-in to TM-X shutdown system, and electronic Unit Control Panel (UCP) enables recording of trip history for ease of troubleshooting and eliminate unsafe conditions, MBP is applicable at unmanned remote platforms with minimum daily man-hour visit.
Integration of the Pressure Depletion in Static Model to Improve Resources Forecast for Future Development of Deltaic Mature Peciko Field
Authors: Roussel S. , Akbar E. , Herawati S. , Muhazir Y. , Herwin H. , Schulbaum L. 
Published: October 2015

Abstract
Peciko is a giant gas field located in offshore Mahakam delta, Indonesia. Hydrocarbons are accumulated in multi-layer reservoirs corresponding to several disconnected stacked distal mouth bars and occasional channels. The trap consists of a 4-way dip closure. The field is producing since 1999 and the reservoirs are depleted with strong variation from one layer to another. Building dynamic reservoir models of a mature field with ~90 layers in production and roughly 300 Geological Pressure Units (GPU), which are then updated regularly taking into account data of newly drilled wells, is very complex and time consuming. However, locating and quantifying the depletion are keys to identify the under-developed areas and to launch additional infill wells. In order to overcome the challenges, to save time and gain reactivity, an innovative workflow has been developed. This workflow encompasses dynamic data and synthesis from production history and allocation, and P/z analysis for pressure depletion modeling, all integrated in the static model. This static model then becomes the tool to support the collaborative works of geologists and reservoir engineers.
It is observed that the pressure depletion is function of net sand stacking, stratigraphical units and gas production which is related to the well spacing. The depletion modeling is based on the pressures measured at wells and actualized to certain time then distributed for each layer in the static model using the net pay as geological constraint. Depletion decline rate is derived from formation pressure measurements & PLT data per layer. By predicting the current pressure, present hydrocarbon-in-place can be estimated and mapped. Gas material balance (P/z analysis) at well level is analyzed in association with well intervention activity (perforation, zone change, and water shut off) to quantify the remaining connected gas-in-place. Allocation layer by layer is then performed based on the production gain after intervention and reservoir properties / pressure or reservoir contribution from PLT results. The results are integrated in the static model through an iterative process and help to identify un-drained areas, thus revealing incremental resources for the future wells. The final result of this method is a remaining hydrocarbon-in-place stacked map used to define new development wells and their associated resources in Peciko field.
The innovative automatic workflow involved an integration of many data and analysis from more than 100 wells with more than 90 producing layers that can be up-dated easily in reasonable time. The method is user friendly, straightforward and applicable to other fields.
A Case Study of a Coiled Tubing Gas Lift Pilot Project in the Cooper Basin, South Australia
Authors: Vasquez Rivas F. R. , Bon J. 
Published: October 2015

Abstract
A Coiled Tubing Gas Lift (CTGL) pilot project was implemented in a light, volatile oil reservoir of the Cooper Basin, South Australia. This paper presents the full lifecycle of the project, from concept initiation to execution and first measured field data.
High pressure lift gas was injected through ¾" coiled tubing, installed inside existing tubing strings and hung from the wellhead. Implementing gas lift in this manner avoided recompletion of the wells and minimised costs. A trial on two wells at a neighboring field was executed in mid 2011 this trial was a world first for ¾" coiled tubing deployed gas lift.
Formation Testing and Evaluation in Challenging Wellbore Conditions: An East Asia Case Study
Authors: Kyi K. , Haddad S. , Ooi A. , Chouya S. 
Published: October 2015

Abstract
Evaluating hydrocarbon columns, reservoir fluid types, contacts and productivity has been challenging in East Asia, especially when open hole well challenges are encountered. Initial openhole attempts are at times unsuccessful in proving significant hydrocarbon potential mainly due to severe losses, high differential pressure or bad hole conditions. The need for a new formation evaluation strategy became necessary to secure critically needed data for the prospect evaluation. The objectives, apart from establishing the presence of hydrocarbon column, is to optimise well drilling execution in a safe and timely manner. In addition to losses challenge, wells encounter hole stability issues with shale being overpressured and potential presence of H2S, whereby its level need to be determined onsite for completion strategy.
To meet the objectives of these wells, an alternative formation testing and sampling strategy has been adapted. The reservoir fluid evaluation was postponed until the open hole was cased. The formation evaluation with Wireline Formation Tester (WFT) was performed in two stages, the first stage was to confirm the presence of cement isolation at the hydrocarbon intervals, and the 2nd stage was to perforate intervals at the zones of interest to confirm the hydrocarbon columns by downhole fluid analysis and sampling.
This case study will discuss reservoir rock and fluid evaluation in cased hole with WFT. Reservoirs of interests are successfully evaluated and representative samples are successfully acquired without any operational issues. Recommended evaluation strategy and best practice supported by field data will also be presented in this paper
Rigorous Safeguard for Wash Tank Roof Demolition
Authors: Kayely Boris Victor , Wiryawan Sony Aria 
Published: October 2015

Abstract
Wash Tank T-03 in Bangko Gathering Station had been operated for 40 years. Its capacity was 56,000 bbls with 100 ft diameter and 40 ft height. Based on last inspection report the roof was corroded and perforated. Prior to demolition work it was found that the condition of the roof was worse than expected.
As preparation for demolition work, the tank must be cleaned from any hydrocarbon. Considering the roof condition, it was forbidden to enter the tank for cleaning activity. Hence cleaning activity could only be done from outside of the tank (by using man holes). By cleaning from outside of the tank, the jetting pressure of cleaning equipment was not enough to clean upper part of shell and roof. Therefore demolition work by using cutting torch (hot work) was not allowed to prevent any fire incident.
Project team looked for other alternatives to demolish the tank such as by using excavator, water jet cut, and a self-propelled pipe cutter. By considering the availability, applicability, cost, existing condition, and space needed, it was decided that hot work was still the best method. Mitigations were needed to eliminate risks due to hot work. Blower and gas detector with prove were installed to eliminate fire risk. Upper part of shell and roof was cleaned by utilizing fire hydrant with modified hose.
This paper will discuss Wash Tank T-03 roof demolition since it was the critical part. The roof demolition was divided into three main steps: load test on roof, horizontal life line & pipe post anchor installation, and roof demolition.
The load test was conducted to ensure that a worker might safely work on the roof. Horizontal life lines were installed as safeguard for workers while working on the roof. A rigorous safeguard preparation was done including the important considerations for horizontal life line design like dynamic load, free fall distance, forces on the worker, fall clearance, and compatibility of fall arrest equipment. These were analyzed in accordance with existing international standards (ANSI/ASSE) and thoroughly discussed among engineering and construction team to capture all potential risks that might happen during roof demolition work. Even though the safeguard (life line) had already been installed, there was also special method to demolish the roof to minimize the risks.
Wash Tank T-03 had been safely demolished with zero incident. It was demolished in 5 (five) weeks with 60% time for roof demolition. But the main part was the rigorous preparation of demolition work, which took more than 2 (two) months preparation work to ensure that all potential risks were minimized and mitigated.
Refracturing Strategy for Sevensprings Oilfield in China Based on Geological and Engineering Characteristics
Authors: Ren Jichuan , Guo Jianchun , Deng Yan , Zhang Lihui , Lin Hai 
Published: October 2015

Abstract
Sevensprings oilfield is one of the oldest mature-flood fields with target stratum between 1000 and 1200m TVD in China with Strong permeability heterogeneity within the range of 0.01-50mD. Most of its wells have been fractured. But for now, the fractured wells have lost their power to maintain productivity. Early analyses show the wells have gained different production dynamics and the stress field around bottom hole was unclear after nearly 20 years water-flooding. Without a proper refracturing strategy, it still could not awake the wells properly.
This paper presents a novel method to determine the refracturing strategy and the priorities of the candidate wells by comprehensive analysis, which considers reservoir properties, remaining oil distributions and induced stress fields. Application shows this method is effective and it can provide a reference for the analogous reservoirs to develop refracturing strategy. First we found out the basic situation of remaining oil and reasons for low-yielding of different wells under various fracture orientation and stratigraphic features through simulation. Combined with these two factors, we can divide the wells into different types which represented by residual oil distribution and location characteristics. After this, we obtained the induced stress field through marching the Waterflooding history. Through analyzing the hydraulic fracture steering angle and steering range, we can figure out the feasibility of steering fracturing to each well type. At last, we made a productivity simulation for each well type with corresponding feature models and fracture steering possibility. Based on this, we can develop the suitable refracturing strategy for every well type and gain the priorities according to the simulated productivity increment.
The novel method established in this paper has been effectively applied in Sevensprings oilfield. Before this, there were more than ten well had been refractured, the average productivity growth rate was 34%, and some wells came to capacity drop because of incorrect treatment. Based on this method, we chose several candidates from more than 100 wells prepared to be refractured. And three of them have already been processed. All of them achieved preferable stimulation response. 3-3 shows an increasing fold of 3.85 from 2.57 t /d to 7.64 t /d. Shen-27 shows a daily production increase of nearly three times from 2.57 t /d to 7.64 t /d. Nowadays, larger-scale application was ongoing
Application shows this new method to determine refracturing strategy and well stimulation priority is effectively. And it can provide a reference for the analogous reservoirs to improve their re-stimulation response.