bluuebunny/crossref_metadata_2025 huggingface dataset:
An Effective Method in Determining Pore Pressure by Controlling Bottomhole Pressure While Drilling Narrow Window Wells in the Gulf of Thailand
Authors: Rubianto Irwan , Prasetia Andi Eka , Detrizio Pasquale , Charnvit Kerati , Srisai Wanchana , Follett Meth , Dejdamrongpreecha Warapong , Kudisri Rapee , Meghnani Manoj , Loux Fabrice , Phonpuntin Visarut , Eawprasert Somphop
Published: October 2017

Drilling narrow window wells conventionally have been well known to cause major wellbore issues to the Operator in the Gulf of Thailand. Therefore, managed pressure drilling (MPD) has been deployed since several years ago to mitigate the drilling problems. To ensure safety and optimize drilling time, it is necessary to identify the actual pore pressure while drilling wells with narrow marginin order to eliminate kick, ballooning and loss events.

The use of automated MPD system to precisely control bottomhole pressure (BHP) during connections combined withthe evaluation of bottom up gas trend while drilling enabled the pore pressure to be predicted accurately in almost real-time condition without the need to stop drilling in the Gulf of Thailand. Thus, the narrow window wells were drilled faster with MPD, which was beneficial for the Operator in the area where the fast factory drilling was necessary to make wells more economical. Furthermore, the use of this new method in effectively determining the actualpore pressure provided solutions to the Operator in mitigating wellbore issues at the same time improving drilling timeafter several years of MPD technology implementations. The estimated pore pressure results acquired with the new methodon several narrow window wells were even comparable to the actual wireline logging measurement results.

The objective of this paper is to introduce an effective and efficient method in determining pore pressure (PP) while drilling challenging wells with tight reservoir characteristic by utilizing MPD technology in the Gulf of Thailand. In addition, this paper also describes the drilling strategy, detail procedure and lesson learnedin verifying pore pressure with the new method.
Reservoir Damage Removal by Zero-Cost Hydraulic Fracturing in a Water Injector, Offshore Vietnam
Authors: Huy Vu Huu , Sutherland John , Thuy Pham Thi
Published: October 2017

In Te Giac Trang oil field, wells are completed with monobore design and with thru-tubing perforation carried out offline following the well completion phase. Producers in the field are perforated with underbalanced conditions through gas-lift application, which has resulted in relatively low-skin completions. In 2014 the first water injector was drilled in the field, with the same completion design applied as for the producers, however with no gas lift mandrels and surface gas lift line installed for cost saving. As a result, perforation of the injector was carried out without underbalanced conditions. The well started injection in November 2014 at 4k bwpd, with the bottom-hole injection pressure (BHIP) kept below the formation fracture pressure (FFP). Injection performance was below expectation, therefore in November 2015 re-/extended-perforation of key sand layers was carried out in order to increase the injection rate. Well injectivity however significantly reduced immediately following the re-/extended-perforation.

Pressure fall-off (PFO) tests were carried out on the injector, indicating significant near-wellbore damage following the re-perforation. Skin factor increased from +14 before the re-/extended-perforation to +50 afterwards. Impairment of the well injectivity was expected to be due to debris plugging the perforation tunnels. After thorough review of the options for remedial treatment, it was proposed to hydraulically fracture the formation using the existing water injection system. The objective of this treatment was to create and keep fractures open over a period of time, so that debris in the perforation tunnels could be pushed far away into the formation.

The treatment was carried out in February 2016, during which the water injection rate was increased to 12k bwpd, with BHIP significantly higher than FFP, and maintained at this over 3 days. PFO testing following the treatment indicated successful damage removal, with skin factor reduced to + 10. Subsequent well injection rate has been stable at 8k bwpd, with BHIP lower than FFP.

This paper describes the process of injection well performance evaluation, including PFO testing, acquiring reliable FFP, and application of remedial treatment through proppant-free hydraulic fracturing. The paper also covers the lessons learned on the design phase of injection well completion, on perforating and on the capacity of the water injection facility.
Bekapai 2B Brownfield Modification Project: Challenges, Execution Strategy and Lesson Learned
Authors: Budiarko A , Setyawan H
Published: October 2017

Bekapai, the oldest offshore field in Total E&P Indonesie, is a mature oil and gas field located in the offshore Mahakam Delta, Indonesia and discovered in April 1972. All Bekapai production is transferred to offshore Bekapai process facilities to separate and treat liquids and gas before sending them to the onshore processing centre in Senipah. Bekapai Redevelopment Phase 2B Project ("the Project"), a brown field project, is aimed to modify 5 offshore platforms (BG, BL, BA, PP, and SWPK) and debottleneck Bekapai field export capacity by installing new 12" subsea pipeline which will interconnect Bekapai and Peciko Field. The Project presents significant challenges in term of technical, cost, and schedule. It needs to be delivered within 15 months after FID (Final Investment Decision). Hence, the Project is the fastest and biggest offshore brown field modification done by Total E&P Indonesie.

This paper will describe the technical, cost, and schedule challenges of the Project and how the PMT (Project Management Team) dealt with them without compromising safety, especially in avoiding schedule and cost slippage, the two aspects often found in projects and even worse for the brown field ones.
Managing Risks in Relief Well Operations: From Planning to Execution
Authors: Poedjono B. , Macresy L. , Sikal A.
Published: October 2017

The complexity of drilling a relief well requires a robust workflow, which defines all actions to be undertaken at each phase. This workflow is used for decision making at every organization level from the field level to management.

To ensure successful execution, all risks must be identified, and detailed preventive and mitigation actions put in place. These actions reduce risk to an acceptable and reasonably practical level at all times.

The relief well drilling process needs to be consistent and must contain these key elements: A multidisciplinary team with clearly defined roles and responsibilities at each operations step for optimal communication.A thorough understanding of relief well techniques, methodologies, and processes, including various solutions. These solutions must be confirmed with simulation, communication techniques, well control and fluid dynamic killing modelling, relative positioning with various measurements and their uncertainties, and drilling in presence of magnetic interference.All team members and third parties should use drilling simulations during the planning phase to identify any gaps, and ensure redundancies are in place. Scenario planning will ease the go/no-go decision making during execution.Incorporating existing workflows into the entire relief well process, such as anticollision risk management and hazard and risk control, to reduce the risk of having multiple sidetracks or having to drill an additional relief well.

This paper will present the relief well workflow process and provide insight into the seven phases of the workflow, including planning, approach target, locate target, follow target, intercept target, killing operations, and plug and abandon operations.
Sisi Nubi Dashboard: Implementation of Business Intelligence in Reservoir Modelling & Synthesis: Managing Big Data and Streamline the Decision Making Process
Authors: Sukapradja Aldyth , Clark Jesse , Hermawan Hermawan , Tjiptowiyono Soegianto
Published: October 2017

Sisi and Nubi (SNB) fields are two adjacent primarily gas fields located 25 km offshore from the modern Mahakam delta These fields are complex from a reservoir management point of view with hundred thousands of Static & dynamic data, and continuously increase by time. Reservoir synthesis and geomodel update are always on-going process with numerous QC, data mining & data manipulation. In brief, Sisi Nubi data management & synthesis challenges are: (1) Enormous size of static & dynamic data (2) Numerous Data mining & data manipulation (3) Rigorous Geomodel QC and reporting.

Business Intelligence (BI) is the philosophy of this study; it is a set of techniques and tools for the acquisition and transformation of raw data into meaningful and useful information for business analysis purposes. The goal of BI is to allow for the easy interpretation of these large volumes of data.

The Sisi Nubi dashboard is a self-service business intelligence tool that was design by the asset to answer & streamline the database management and reporting, hence give more time for the asset's geosciences team to do the reservoir synthesis and optimize the study time by automate the data mining & manipulations. The Sisi Nubi dashboards composed of an automated workflow in the geomodeling platform for the data mining, combined with spreadsheet based tool for the data manipulation and presentation (dashboard-ing).

The result of this study presented in 6 unique dashboards, representing 6 difference perspectives of the user. These dashboards are linked to the SNB geomodel and allow instantenous update. Combined with the updated SNB geomodel workflow, the collaboration of two tools has proven significantly streamline the geomodeling reporting & synthesis efficiency.
Breaking Records Using an Innovative Organophilic Clay-Free Invert Emulsion Fluid OCF-IEF to Drill the Longest Well to Date in the United Arab Emirates 35,800 ft
Authors: Nasrallah Mena , Vinci Matteo
Published: October 2017

This paper discusses the successful design, laboratory testing, and performance of an innovative, low solids, organophilic clay-free invert emulsion fluid (OCF-IEF) used to drill the reservoir section of an extended reach drilling (ERD) well. This specially designed drill-in fluid helped maintain the key ERD factors within the specifications necessary and set new limits for drilling performance, thus maximizing the horizontal section displacement/reservoir drainage and production output. ERD wells necessitate extensive design, planning, and close monitoring of various parameters to successfully complete the drilling and completion phases and deliver production expectations. While evaluating the feasibility of drilling the longest well in the UAE, establishing appropriate fluid system properties was a key focus area. The rheology profile was optimized for hydraulic management, hole cleaning, and fluid stability. The ground marble bridging package was designed to be minimally damaging. Lubricity and rate of penetration (ROP) maximization was also addressed by designing a low solids OCF-IEF in which the base brine was calcium bromide (CaBr2). This paper discusses the processes used during the planning phase, including laboratory testing and hydraulic simulations, and the procedures followed during the execution phase, which helped ensure trouble-free performance during drilling operations. Proper planning and execution using the best-available drilling practices helped enable the drilling of this record-breaking well, without significant issues that could impact rig time. The selection of an OCF-IEF to provide low equivalent circulating density (ECD) performance in a fragile gel fluid, with low sag risk, was fundamental to achieve the necessary fluid properties. The low solids design helped improve deployment of the weighting material (ground marble) compared to similar fields in which more conventional organophilic clay-based fluids were used. More than 18,000 ft were drilled in nine days with an average ROP of 2,000 ft/D, which set a record ROP in this field. As a result, the drilling operations were completed ahead of schedule and below the authorized financial expenditure (AFE). Additionally, the production rate was five times greater than estimated, thus confirming the anticipated nondamaging property of this OCF-IEF. The OCF-IEF design and performance brought within reach reserves not easily accessible using conventional mud systems and drilling techniques. The increased reservoir drainage resulted in significant productivity gains. This fluid can also be used during other operations to reach new target depths to maximize production.
Staying Ahead through Built-in Automated Approach for Well Modelling in Gas Fields
Authors: Baghdadi F. , Yin K. Yin , Madon B.
Published: October 2017

In oil & gas industry, it is evident that digitalization has become the leading technology to improve interactive data analysis in amultidisciplinary team. Exploitation of data has been a real challenge especially on mature fields with high real-time data frequency extraction on day to day basis. This paper aims to increasethe integration of data and workflow for building well models.

An automated workflow through programming has been implemented in offshore Sarawak, Malaysia involving three (3) main processes, which are:

procedures to use historical data to select IPR and VLP correlation for well models a workflow to predict well IPR using available surface data a built-in application to auto-match well models to selectthe most representative IPR model based onsufficient production data to be used in forecasting

The well performance and technical potential of the field was evaluated in accordance to this workflow, resulting in significant time-saving when analysing the massive pool of data. This enables the proliferation of real-time data usage promptly.

Employing this workflow minimizes misinterpretation of frequently ignored erroneous information compared to the conventional method. Greater reliability of well analysis using workflows helps to avoid perpetuating bias tendencies on data used for model calibration or quality check. This will result in better technical confidence needed to make decisions to move forward with development plans for a wide range of production rates and operating conditions. This paper will investigate the impact of using incorrect IPR or VLP versus the results of this workflow based on the same historical dataset. It will also demonstratehow the built-in automated process adds value in improving the understanding of well performance while ensuring that the models are calibrated to the entire historical data as accuratelyas possible.
Reservoir Mapping While Drilling Tool Overcomes Geological Uncertainties- Case Studies From Offshore Malaysia
Authors: Yen Philip Tan , Yen Kok Kwi , Hassan Nur Atiqah , Kyi Ko Ko
Published: October 2017

Reservoir Mapping While Drilling tool, consisting of a Deep Directional Electromagnetic Propagation Resistivity (DDEM) Logging While Drilling (LWD) tool and associated imaging software can detect bed boundaries and map reservoir bodies laterally beyond the wellbore being drilled. It has been successfully deployed to resolve and overcome geological and reservoir uncertainties when drilling wells offshore Malaysia. In Case Study-1, the DDEM tool was used to locate and navigate the drilling borehole assembly within a turbidite target reservoir successfully. In addition, the Reservoir Mapping While Drilling tool was able to detect and map a hydrocarbon bearing sand ten metres below the original borehole. In Case Study-2, the DDEM tool was used to identify the current Gas Water Contact (GWC) in a carbonate field which was experiencing high water cut early in the life of the field. In Case Study-3, the DDEM tool was used to determine the Top of Carbonate (TOC) in a carbonate gas field. It was critical that the top of carbonate be identified correctly, as the surface seismic data was relatively poor and was not able to pinpoint the TOC accurately. In the first case study, the hydrocarbon pay sand would have been completely missed if standard LWD tools alone were used to drill the well in a mature field. In the second case, the DDEM tool was able to locate and map the current Gas Water Contact (GWC), which was found 35 metres below the wellbore, in the carbonate gas field. It was found that the water was being produced through a karst zone, although all the previous production wells had been drilled horizontally way above the original GWC. In the third case, the DDEM tool was able to detect the Top of Carbonate, thereby allowing to set the casing shoe above the TOC. The plan was to set the intermediate casing shoe just a few metres above the TOC to avoid encountering severe mud losses when drilling through the carbonate reservoir. This paper will discuss the various steps involved in planning, designing and drilling of these wells using the DDEM tool with the associated reservoir mapping software. The methods used in imaging the reservoirs of interest and the bed boundaries and results obtained will also be discussed.
Development and Field Application of Proxy Models for Predicting the Shale Barrier Size using SAGD Production DATA
Authors: Kim Min , Shin Hyundon
Published: October 2017

There exists high uncertainty in modelling an interbedded shale barrier in heterogeneous oil sands reservoir, which causes a critical impact on SAGD performance. At present, despite the rise of research on shale barrier issues, few studies have attempted to address the prediction of shale barrier size except for 4D seismic data interpretation. In a shale interbedded oil sands reservoir, the SAGD production data such as the oil rate and steam-oil ratio (SOR) increase up to a peak point and decreases down to a trough point again, and the points are named inflection points (IP).

In this study, proxy models were developed for predicting the shale barrier size using reservoir parameters and the IP of SAGD production data. In addition, a field application was carried out for verification of the developed proxy models using the data from Suncor's Firebag SAGD project, Alberta, Canada.

The results of the screening analysis showed that the key parameters affecting IP of the SAGD production data were the reservoir thickness, horizontal permeability, vertical-horizontal permeability ratio, oil saturation, shale width (WD), shale length (LN), and vertical location of the shale (VL). The key parameters were selected and multiple simulation cases were generated using a latin hypercube sampling. As a result, the applicable proxy models for predicting WD, LN, and VL were developed by statistical analysis of the reservoir parameters, shale size and location, and IP. The statistical results of the proxy models show that the adjusted R-squared and predicted R-squared are high.

As a verification procedure, 3-D simulations were performed to reconstruct the predicted WD, LN, and VL, and the oil production profiles of the field well pairs were compared with the simulation results of the reconstructed shale barrier.

The oil production profiles show the similar trend between the simulation results of the reconstructed model and the field SAGD production data. Therefore, the developed proxy models can predict the shale barrier size properly, and may be useful for the field application.
Managing the Known and Unknown Risks - An Old Well Reabandonment Story
Authors: Mohd Mokhtar S. R. , Ardi A. B. , Wibisono R. , Zakaria M. , Shabudin A.
Published: October 2017

Located about 50 km from the nearest commercial city in East Malaysia, lies an old exploration gas well that was drilled and abandoned in 1952. This well, identified as well Orange 1, was observed to be leaking by a housing developer company in 2013 as they were progressively constructing houses in that area. This resulted in temporarily suspension of the construction works in fear of potential harmful gas leakage and explosion.

The well Orange 1 is a high pressure exploration gas well that was drilled to about 12,000 feet and immediately abandoned back in 1952. Given that this well was never opened to production, the reabandonment design had to be done based on the well still having the virgin reservoir pressure with the potential of flowing up to 7000 psi. This alone imposed several technical and operational challenges which requires lengthy and detail engineering approach. The reabandonment in many ways simulated drilling into a shallow gas zone. There was limited information available regarding the well and the original cement plugs were neither checked for depth nor tested during the original abandonment and their very existence was based on the number of sacks of cement reported to have been pumped in the drilling reports. It was theoretically possible to drill through the top 200feet cement plug and find full reservoir pressure at surface, so equipment and procedures had to be in place to accommodate the worst case scenario. Since this well was in the vicinity of a housing area, additional public risk and logistical challenges also had to be managed to ensure the deliverables are achieved in the safest manner.

This paper outlines the overall integrated project management process to evaluate all the down hole and surface risks, environment, public interest and logistical challenges and its related planning, solutions, risks management and lessons learnt from the 6 months execution phase. As this is the first land well reabandonment in Malaysia, it has now become a reference and benchmark for any near future land well reabandonment works. Together with the service sector, PETRONAS also carried out design and operation optimization process to even further enhance the execution.
Shallow Light Architecture: A Viable and Cost-Effective Solution for Marginal Reserves in Tunu Shallow Development
Authors: Handoko A. I. , Bimastianto P. , Maulana M. D. , Agriawan C. , Brahmantio R. A. , Abidiy I. , Setiawan T.
Published: October 2017

The current development of Tunu field level has reached a mature level. Finding target for new wells with adequate reserves to pass the economic cut-off limit has been a challenging task. In addition, with the recent low gas price environment, completing these marginal wells using currently proven Gravel Pack (GP) well design makes these wells uneconomical.

Answering the challenge, and with alignment to cost culture program, Total E&P Indonesie launched a collaborative project aiming for cost-effective wells against well reserves. Shallow Light Architecture (SLA) well design was introduced as the outcome of well architecture simplification process. For sand control, a successful period of trials of chemically-enhanced sand consolidation has boosted the confidence to implement sand consolidation on the industrialization phase as primary sand control in SLA wells.

This paper aims to describe a brief development of the technology, implementation, and results for the operator.
Driving Efficiency in Idle Wells Restoration through Risk Sharing Integrated Operations
Authors: Mohd Mokhtar S. R. , Wibisono R. , Zakaria M. , Shabudin A.
Published: October 2017

In the past few years, operators in Malaysia have intensified activities to restore idle wells. This was driven by the requirement to sustain existing production, high oil price and availability of resources. However, the success rate of each activity and efficiency of the operation was not encouraging as it was averaging at about 60%. This has become a huge concern to Malaysia Petroleum Management (MPM), the regulatory body of PETRONAS as 40% of investment spent to restore these idle wells did not yield the production gain that it was targeted. MPM sees this as value leakage that needs to be reduced significantly during current low oil price scenario.

A thorough analysis of the overall well intervention activities in Malaysia was carried out especially on the activities related to idle wells restoration. The focus was very specific to this area because idle wells percentage is as high as 50% from the total number of wells in Malaysia. This translates to a technical locked in potential of about 80,000 barrels of oil per day (BOPD). Most of the time, even though the planned cost of an activity is below the regulatory Unit Enhancement Cost (UEC) threshold to begin with, the actual cost surpasses the planned cost after the execution due to inefficiency and the small allowable error margin. With the low oil price scenario, coupled with low gain potential from idle wells, it was deemed necessary for MPM to put in a different strategy to manage this inefficiency and value leakages. After a series of engagement with the operators, root causes were established which includes inefficient resources utilization, poor technical solution, poor planning, weather limitation and lack of collaboration with industry key solution providers.

This paper outlines the process that MPM have implemented to provide the operators and service sectors a contractual platform at which all stake holders can share and formulate a win-win investment portfolio. The philosophy of the strategy is based on a risk sharing mechanism where operational efficiency and success rate of an activity are the main drivers to guide both the operators and service sectors. Specific Key Performance Indicators were defined to ensure the risk sharing mechanism is fair for stakeholders.

After the first implementation of this new strategy, MPM have seen the positive impact on the efficiency and success rate of both the operators and service sectors. Efficiency have raised to about 92% and success rate to about 85%. Efficiency which is defined as the percentage of work time of total time spent on the activity, played an important role in ensuring value leakage was reduced. This new mode of execution have now been further expanded to include production enhancement and well abandonment.
Fit for Purpose Behaviourism; a Design Culture
Authors: Siboro M. , Prabowo A.
Published: October 2017

Total E&P Indonesie (TEPI) is an integrated oil and gas company based in Mahakam Delta (Mahakam PSC), East Kalimantan. The fields are mature, with declining reserves found on existing & newly drilled well. Global situation dictates oil and gas industries (Including TEPI) to adapt by controlling cost (CAPEX & OPEX). Change Culture Compete on Cost and Deliver (4C&D) becomes the daily practice as it is considered as the means to survive. The change of culture & way of working has been integrated in the design methodology of the surface engineering team. The mindset is to implement "fit for purpose design", by utilizing existing material on stock and/or optimizing existing facility (instead of capital procurement). This approach is performed as such as design requirement is adapted to deliver the most favorable safe design. The methodology has been translated into several success stories; One of them is the revival of preserved gathering facility through minimalist concept. The project design execution embodied the "fit for purpose" design as the facility was revived with minimal effort (instead of complete reinstatement as per original design intent), with most material utilized from existing facility or existing stock. From process engineering and safety review, change of operating philosophy is foreseen when opting to the minimalist concept. However, with proper risk evaluation that was performed throughout the engineering phase, all possible risk has been identified, assessed & properly addressed. Furthermore, the change of operating philosophy has been assimilated seamlessly by the site operation team. The reactivation project has been completed smoothly on time (gas in before 1/4/2016), below budget (USD 1.3M realization / 1.5M budget) and maintained high safety standard as TEPI core value (no HSE incident). Currently, the facility has been put on stream, with recorded peak production of 16 MMscfd. This example had perfectly demonstrated that the change of mindset has been profound in delivering design that is suited for current economical environment. The willingness and the courage to get out from the comfort zone is one of vital element for success. The culture of opting to "fit for purpose" design as base case has been embedded in the DNA of TEPI surface engineering team, making it as one of the mandatory tools to survive.
Understanding Multi Zone Single Trip Gravel Pack Performance Improvement Process Using Technical Limit Methodology in Mahakam Delta
Authors: Wijaya R. , Muryanto B. , Wahyudhi F. , Styward B. , Sinaga H. A. , Masrur M. , Syafrudin M. , Kundoko B. , Daris M. F. , Nugroho H. M. , Ridhonmas A.
Published: October 2017

This paper presents analysis of Multi Zone Single Trip Gravel Pack (MZ-STGP) experience and performance in Total E&P Indonesie for more than decade in challenging field environment and global market condition. MZ-STGP has been utilized as a robust sand control completion methodology for sand prone reservoirs in Mahakam Delta since 2006. It enables saving of 3-6 days of rig time depending of well configuration compared to classic stack Gravel Pack (GP). More than 250 wells have been completed with satisfactory result and later drive the company business strategy.

Since the downturn of oil and gas industry in year 2014, a "cost efficiency project" called 4C&D (Change Culture, Compete on Costs & Deliver) was launched by Total to targets sustainable culture change and reduction in cost. It involves all aspect in company activities included in scope all operating, whether Total operated or operated by others. This project comprises a number of action plans – "roadmaps", where MZ-STGP became part of it. The target was to have an approach to identify current MZ-STGP performance and understand how to improve it by utilizing certain methodologies and tools.

The purpose of this paper is to provide the MZ-STGP practical steps implemented over the past few years using Technical Limit (TL) methodology. This methodology is expected to improve the efficiencies in whole aspects mainly related to performance monitoring as well as maintain low cost in order to have synergy with 4C&D spirit. The approach was influenced by comprehensive statistical data and ideas which resulting changes in the procedures as well as development in technology and equipment. As a result, a step change improvement in MZ-STGP completion performance was successfully achieved.
Right of Way Surveillance, Maintenance, and Higher Production Opportunities on Banyu Urip Export Pipeline
Authors: Amanu D. K , Kartika R.
Published: October 2017

The Banyu Urip Onshore/Offshore Crude Oil Export Pipeline is 20 inch carbon steel extending for +/- 96 km. As the pipeline is the key facility to transport Banyu Urip crude for export, the integrity management of the pipeline is vitally important. There are several aspects of the integrity management program; two will be focused on in this paper: Right of Way (ROW) maintenance and as-built capacity analysis to support potential varying production profiles.

Pipeline ROW maintenance is challenging due to several reasons: (1) the agreement made to give access to local communities who previously owned the land to enable farming, now creates access challenges for inspection and surveillance. (2) Managing ongoing local government and 3rd party infrastructure projects above the pipeline. (3) Geographical andweather conditions impacting accessibility. (4) Boat surveillance limitations on the offshore section of the pipeline. Proactive external engagements and new technology applications are considered key to a successful ROW maintenance program.

Proactive community engagements include effective socialization to local communities about the importance of pipeline integrity and the hazards asscoated with buried/submerged pressurized hyrdrocarbon pipelines. Additionally, establishing and maintaining strong government relations are also important to ensure potential infrastructure development around the pipeline ROW will not harm the pipeline or impede implementation of the pipeline integrity management program. Government alignment is also a key enbler for successful community engagement.

Utilization of new technology has enabled the operator to tackle some ROW accessibility challenges. The use of drones has resulted in patrol cost optimization compared with using helicopters.

Following pipeline construction and commissioning, various as built studies have been performed to test the pipeline across a range of production profiles and to determine if a higher operating envelope than original design basis could be established. These studies included detailed surge and stress analysis. Surge analysis was performed to calculate maximum pressure expected in pipeline; while stress analysis was performed to ensure pipeline integrity at higher production rates. The result shows the pressure in the pipeline could increase to 78 bar (26% increase), and flow rate increase to 374m3/hr (9% increase). Stress analysis confirmed that pipeline is capable of operating at a higher envelope (MAOP 83 bar at 78 degC, relieving capacity at 688 m3/hr – a 34% increase vs design basis).

This engineering assessment of the existing as-built facility can supporting Indonesia through enabling increased production without additional pipeline infrastructure cost.
Maintaining Safety Performance in the Context of High Drilling and Completion Activities - A Lesson Learnt from More than 2 Years without LTI
Authors: Therademaker Ricky , Siswanto Agus , Hidayat Ramadhan
Published: October 2017

Company operated 7 rigs during the period on 2011 – 2016. The drilling and completion operation are categorized as offshore activities by using submerge swamp and jack up rigs. Approximately 100 wells were drilled with 4 million man hours in average within a year. The challenges are the high proportion of direct involvement of human resources with equipment and materials, turnover of personnel and various educational background levels of the workers. In 2014, there were 11 recordable injuries where 4 of them are Lost Time Injuries (LTI). Based on the incident analysis, the root causes are mainly related to inadequate supervision and leadership.

In order to enhance and maintain the safety performance, there are two categories of intiative i.e. HSE culture / communication in order to maintain personnel awareness on safetyAudits and inspection in order to monitor and control the operation

The Rig Action List (RAL) is monitored to ensure no compliance and conformity issues. The Drilling Manager performs regular reviews planning, action lists, objectives and targets as part of the HSE Management System implementation.

Well Construction (WLC) Division reached 2.5 years without Lost Time Injury (LTI). The safety performance record is an outstanding result, considering the magnitude of the drilling operation on site.
How to Solve High Water Cut Well Problem in Mature Oil Field, Case Study: Application of Modified Completion Fluid Treatment in WW D-29, WW H-12, II A-22 Wells
Authors: Afi F. N. , Gunawan H. , Widiatmo R. , Waskito L. B. , Nugroho P. , Luthfan M. , Prayogo R. , Suryana A.
Published: October 2017

Dealing with mature offshore oilfield has complicated problems both surface and subsurface. In the reservoir condition high water cut wells make some bad impact in the production stages. Liquid handling facilities, tubing pipeline erosion, broken sand control, and high power consumption are several problem caused by high water cut wells. WW is an offshore oil field which has developed since 1990s with OOIP 758 MMBO. This reservoir was divided into several layer, 33 series is depleted reservoir with water injection since year 2000s (RF 23%) and 35 Series has strong water drive as its driving mechanism (RF 56%). Almost 85% of the oil wells is producing with water cut more than 97%. Increasing water cut or even watered out phenomenon was frequently happen during production stage, some of this problem was happen after well intervention such as after pump replacement. This paper will show the successful case of decreasing water cut significantly from WW D-29, WW H-12, II A-22.

Laboratory test was firstly done to check the compatibility test of the rock with modified completion fluid. This chemical was mainly works as phase change water control and oil stabilize well for completion fluid. It was pumped simultaneously with regular completion fluid (filtered drill water and additives). Killing well was mandatory procedure when shut in wells will be repaired. GGR team supported by Production and Workover Team did integrated study to choose the chemical and well selection based on some criteria.

WW D-29, WW H-12, and II A-22 are wells which have implemented modified completion fluid treatment. Those wells are produced from sandstone reservoir and drilled more than 10 years ago. During production period, water cut was significantly jumped due to several reason, such as pump replacement job, re-start up after the well trip off, etc. The result of the project were very excellent, WW D-29 (from 98% to 86%, gain +/− 180 bopd), WW H-12 (from 80% to 40%, gain +/− 250 bopd) and II A-22 (96% to 75%, gain +/− 130 bopd). These result give a lot of impact of increasing oil production in WW Field.

This paper will elaborate how to solve the problem in offshore mature oil field special case for high water cut wells using modification of completion fluid treatment. We have succeeded increasing oil reserves.
Integration of Casing Wear in Casing Design and Stress Analysis Workflow
Authors: Soong Alfred , Arriffin Muhammad Faris , Rosland Habil Akram
Published: October 2017

An advanced stiff-string model used during casing wear simulation to evaluate the drillstring contact position at any given casing depth can reflect the actual downhole scenario more precisely. The model yields a more representative wall thickness reduction percentage along the casing string by estimating multiple groove positions at each cross section. The simulated casing wear severity is subsequently incorporated into tubular design calculations by amending critical dimensions for each stress criteria to represent the worn tubular operating limits. The integration process reduces the safety margin for the modeled loading conditions that the casing string is expected to withstand during the well's life cycle.

This paper highlights the different methodologies applied during casing wear simulation and discusses how to integrate the results into the casing design and stress analysis workflow to predict the critical failure mode for the investigated tubular string.
Trials of New Designs Lead to Optimized Bit Selection for Drilling through Hard Carbonates in South Mahakam
Authors: Fidiansyah Ardho , Noviasta Bonar
Published: October 2017

The intermediate phase on South Mahakam (SMK) field presented technical and economical challenges due to multiple bit runs, attributable to thick carbonates with Unconfined Compressive Strength (UCS) up to 30K psi. The typical phase is either 12-1/4" or 8-1/2", reaching 1600m long with 90% containing the carbonates. Initially, different configurations of 8-1/2" Polycrystalline Diamond Compact (PDC) bits with durability in mind were selected but failed to deliver performance with more than 1 run required. Poor post-run dull gradings were observed reflecting broken/worn out cutters, and even blades ring out.

A recent campaign on SMK introduced two new 12-1/4" bit designs. First, a Hybrid bit (Roller Cone – Fixed Cutter PDC) was selected following a positive global experience on hard formations. A second trial involved a PDC with a Conical Diamond Element profile in the secondary cutter row – aimed to deliver high loading point to fracture hard formations and ease drill out. Both designs managed to drill the section in 1 run and delivered record speed.

The Hybrid bit managed to deliver at an almost double Penetration Rate (14.9 m/hr) than previous runs. Its durability was however limited by the seal life of the Cone. During run, a real-time monitoring of parameters and Minimum Specific Energy (MSE) was performed to detect for failures. Despite the precautions, a seal was damaged and the bit was undergauged. A control trip was triggered eliminating the cost saved for drilling in 1 run.

Conversely, the PDC with secondary conical elements delivered higher performance (29.6 m/hr) with dull grading allowing for a re-run under the same conditions. The bit became the standard for SMK, continuously delivering the phase in 1 run, a saving of 5 days.

This paper will analyze the cause of the Hybrid bit damage and how parameters monitoring did not pick up failure signals. It will also highlight the success of the bit conical elements in terms of practicality and effectiveness for drilling hard carbonates in SMK.
ELECTRONIC STRUCTURE OF DIVALENT METAL AZIDES
Authors: Gordienko Aleksey , Gordienko Aleksey , Filippov Daniil , Filippov Daniil
Published: October 2017

Ion-molecular metal azides are well known because of their high reactivity, and nowadays they are widely used as energetic materials. Despite the large amount of experimental data exists on such kind compounds, the number of theoretical studies is still not so large. The aim of the present work is to study of the electronic structure of Me(N3)2 compounds, where Me=Sr, Ca, Cd, Hg. All the calculations have been carried out within the framework of the density functional theory with the use of the numerical pseudo-atomic orbitals basis. The results of the band structure calculations are presented in the work together with a maps of total and partial electronic density; the data on Cd(N3)2 and α-Hg(N3)2 are presented for the rst time. The values of band gaps calculated are in good agreement with those obtained by other authors or estimated in the experiments. The all the crystals under consideration, except of α-Hg(N3)2, are predominantly ionic compounds with a relatively small fraction of the covalent bonding. The overall structure of the valence band spectra, as well as the character of conduction band bottom, is similar to other heavy metal azides. The comparative analysis of the data on band gaps led to the conclusion about lesser stability of the heavy metal azides than that of the second group metal azides, what is also conrmed by the experimental data
PREDICTION OF THERMODYNAMIC PROPERTIES OF SECONDARY ALCOHOLS
Authors: Esina Zoya , Esina Zoya , Miroshnikov Alexander , Miroshnikov Alexander , Korchuganova Margarita , Korchuganova Margarita
Published: October 2017

An analytical formula for the enthalpy of evaporation of secondary alcohols has been received using the method of thermodynamic similarity. The relative molecular mass M, Tboil and also the number of carbon atoms in the molecule N are applied as parameters of reduction. A dependence of boiling temperature on the number of carbon atoms in a molecule of secondary alcohol has been provided. A predicting model for the vaporization enthalpy based on the data on critical temperature has been provided. A possibility of application of the similarity theory for the calculation of enthalpy of melting of secondary alcohols according to the known vaporization enthalpy has been considered. The obtained thermodynamic characteristics of secondary alcohols can be used when calculating equilibrium ratios charts. In the PCEAS program developed by the authors (Phase Charts Eutectic and Azeotropic Systems) input data are the enthalpy and temperature of phase transition of pure components therefore the offered models allow to calculate the equilibrium charts of binary systems on the basis of secondary alcohol
ANTIOXIDANT POTENTIAL OF TOMATOES FROM SEEDS TO ENG PRODUCT (OVERVIEW)
Authors: Danilova Maria , Danilova Maria , Skrypnik Lyubov , Skrypnik Lyubov , Leon Begona , Leon Begona , Ivanova Svetlana , Ivanova Svetlana , Pavsky Valeriy , Pavsky Valeriy , Borodina Ekaterina , Borodina Ekaterina , Chaplygina Tatyana , Chaplygina Tatyana
Published: October 2017

Tomatoes are reported to be the most consumed and processed food in the world. The correlation has been specified between the tomato food consumption expansion and reduction in the risk of certain diseases, including cancer. Researchers from across the globe concentrate on tomato and processing technologies to ensure preservation of its physical, chemical and biological properties. A range of researches have been held to analyze capacities to use tomato components known for high antioxidant activity as potential biologically active compounds. Commonly, such studies concentrate on ripen red tomatoes, though works may be defined that studied green, yellow and orange fruits. There is evidence on correlation between qualitative and quantitative fruit properties and agricultural technologies and tomato varieties used. Bio-fertilizers consisting of microorganisms, defining the plant microbiome, favorably work on quality improvement of agrocultural plants, including tomatoes. Limited irrigation, illumination and other conditions that cause internal plant stress and provoke numerous protective reactions result in mixed findings, where the yield depends on other factors (grade, climate, fertilizers, etc.). Tomato derived products are rich in antioxidant substances the same as waste products. A variety of works focused to study processing techniques and their impact on the tomato quality characteristics. Traditionally, thermal effect decreases the activity of various antioxidant compounds, but makes them more digestible when consumed. The UV exposure used for long to inhibit pathogens on surface of fruits and berries, that cause the spoilage during the storage period, showed its potential to increase the antioxidant activity of fruit and vegetable products as they ripen
HIGH TECHNOLOGY SOFTWARE WEB-TOOLS TO SOLVE ENVIRONMENTAL PROBLEMS OF COAL REGION
Authors: Gudov Alexander , Gudov Alexander , Perminov Valery , Perminov Valery , Grigorieva Irina , Grigorieva Irina , Zavozkin Sergey , Zavozkin Sergey , Sotnikov Igor , Sotnikov Igor
Published: October 2017

The paper is dedicated to the pilot system of the computer information portal, that is being designed in Kemerovo State University in order to enable engineers, students, postgraduate students and other users to get an expanded access to solutions of environmental applied problems in Kuzbass. The following elements are considered to be pilot system elements: solution of the grit motion in a klooded shaft problem, virtual laboratory of parallel programming, distributed computer resources access system. The present research is based on the task № 2014/64 of state research “Scientific research organization”
Potential for recycling of suspended solids and nutrients by irrigation of tailwater from tailwater recovery systems
Authors: Omer A. R. , Moore M. T. , Krutz L. J. , Kröger R. , Prince Czarnecki J. M. , Baker B. H. , Allen P. J.
Published: October 2017

Within the Lower Mississippi Alluvial Valley, conservation practices are being utilized to mitigate nutrient loading to streams from agricultural landscapes. This study was conducted to determine the potential to use solids, phosphorus (P) and nitrogen (N) captured by tailwater recovery (TWR) systems for reuse onto production fields through irrigation applications. Seven TWR systems were assessed for seasonal changes in nutrient concentrations and application loads. Samples were collected every three weeks from 2013 to 2015 for seasonal analyses and weekly during the 2014 and 2015 growing seasons for nutrient load analyses. Water samples collected in spring contained greater concentrations of solids than samples collected in winter and summer. In addition, spring samples contained greater concentrations of nitrate–nitrite than samples collected in all other seasons, and spring samples also contained higher ammonium than summer and fall samples. Mean nutrient loads per hectare recycled onto the landscape for an irrigation season were 325.10 kg ha−1 solids, 0.86 kg ha−1 P, and 7.26 kg ha−1 N, with the N being 77% organic. TWR systems can be used to recycle solids, P and N onto agricultural landscapes through irrigation events; however, nutrient loads will not be sufficient to alter agronomic fertilizer recommendations.