bluuebunny/crossref_metadata_2025_split huggingface dataset:
Extreme Underbalanced HPHT Coiled Tubing Conveyed Perforating: KN-Ultra Deep Field Study
Authors: Rosato Miguel , Bakar Mohd Farris , Azmi Fadzliana 
Published: October 2017

Abstract
In order to carry out the first HPHT field development offshore in Malaysia, learning from experience of HPHT operators in the North Sea, a detailed focus on lifecycle and well integrity aspect has been thoroughly emphasized throughout the well delivery phase. At an initial stage in the project, a locally conventional initial design considered the use of TCP to perforate a 7″ liner and then complete the well in open hole with overbalanced completion fluid. This solution carried several challenges that would have affected the safety of the completion process and the future integrity of the well architecture.
A different approach, in which a fully cased hole well is completed in underbalance and then perforated once the completion is installed and tested is introduced for the first time within PETRONAS. The system allowed the perforation of a 400m HPHT reservoir interval in a single run, by using a dedicated coiled tubing deployment system.
The implementation of this completion philosophy permitted to achieve the following milestones: Completion in underbalanced packer fluid, which enhanced the well architecture by reducing potential production casing failure due to extreme loads in case of tubing leak.The use of inhibited fresh water, provided an effective, alkaline fluid that eliminates the very high potential for corrosion created by heavy, high halides completion brines.Safer way to run the completion in a closed, inflow tested environment.Single perforating run, which allowed for a safer procedure for the deployment of guns. There is no deployment of guns under pressure or under exposure to hydrocarbon.If required, especially in very tight reservoirs, there is the ability to displace the well with N2 immediately after perforating (separate runs for stimulation are not required)As soon as the last gun is out of hole, the well is ready for well testing / clean out / production.
This paper covers the design, QAQC, operational and logistics aspects of the KN Ultra Deep'sCoiled Tubing Conveyed Perforating with a final section covering the challenges and lessons learned that may be used by project teams in the future.
Downhole Production Logging for Locating Water Sources in Open Hole Completion Oil Producer Wells
Authors: Yaakob Amirul Afiq , Hutamin Nurhidayah , Sa'aid Hasanah , Salleh N Hajjar , Nor M Hafizuddin , Anas W M , Setiawan Agus , Azraai M , Mariam Siti , Alam Bambang N , Iless N Afifah , Rahman M Zhafran , Amin M Farid , Mohamed Tatmimiddin A 
Published: October 2017

Abstract
The use of open-hole completions in the design of production wells is a particularly appealing choice for oil companies, since it can ensure huge economic advantage compared to conventional cased-hole completions. Nowadays, most operators are looking for more innovative economical well completion design. Swell packer is one of the technology that widely used in open-hole completion strategy with combination of others completion accessories. Coupling the swell packer with open-hole completion application, it makes multiple zonal pressure isolation in the following open-hole completion possible: bare foot condition, predrilled liner, stand-alone screen, open-hole gravel pack or even open-hole fracturing packing. However, few typical implications associated with open-hole completion which complicated further the well integrity and flow performance monitoring.
In 2012, 11 oil producer wells were completed in Field X with open-hole completion and installed with stand-alone screen (SAS), swell packers and double valve float shoes. First oil was achieved in April 2012 with all wells initially producing high oil rate and low water cut. However, towards the end of 2013, some of the wells started to show high water production. Production logging (PL) was conducted at Well #1 to evaluate the flow contribution and water source. It was concluded that the water was coming from the bottom of double valve float shoe. Remedial action was taken by setting a plug for water shut-off and the water rate dropped drastically. In 2015, it was decided to replicate the production/well diagnostic analysis in all open-hole completed wells. Similar results were then observed by production log (PL) and consequently, remedial action was taken accordingly.
The production log (PL) interpretation, historical production plot and surface well test results were integrated and provide the required information to determine the forward production strategy in these open-hole completed wells. This paper will share multiple case studies where water source diagnostics have been performed in open-hole completions, as well as lessons learnt and best practices throughout this process.
Automatic Control Surface Safety Valve: Low Cost Solution to Optimise Production
Authors: Moelyono S. P. , Kusuma P. F. 
Published: October 2017

Abstract
The best way to maintain the base production since there is no drilling, fracturing, and limited rigless activity in mature field (Nilam field) is by reactivating cyclic wells, opening or shutting the well in for certain period of time. Hundreds of string, extensive area, and short period of cycle time make ineffective job since there are limited number of operators to handle. A design of automatic system to open or close cyclic well is created to solve the problem.
This automatic system named "autocyclic" modifies well instrument system. The method is by adding a pair of pressure switches to create pressure span between pressure setting value to open and close the SSV. When the shut-in pressure reaches the open pressure setting value, the SSV will automatically open and gas can flow, when the flowing pressure decline and reach the close pressure setting value, the SSV will automatically close. Using SSV as open and close mechanism does not eliminate its main function as safety valve.
The application of "autocyclic" is optimized based on well flowing time and pressure. The value of pressure switch setting is adjusted based on the history of the well and can be optimized to get the optimum cumulative production. Due to safety reason related with plant, the well is still choked. The result is astonishing reflected from there are 7 string installed in 2016 with total gain 1.31 MMscf compared with those wells produced in natural cycle. In the first semester 2016, those wells contribute 0.1 Bcf as cumulative production. These modifications cost around $ 608 per installation that mostly uses ex-used materials. In addition to low cost and production gain, "autocyclic" helps operators to prioritize more important tasks in the field.
Autocyclic is a simple double advantages technology. In addition to safety, well flowing cycle can be optimized and improved.
Eliminating Non Productive Time While Drilling in Southern Sumatra Field with Pressurized Mud Cap Drilling
Authors: Zein Joydi , Iskandar Yoshua , Dharma Dion , Ali Ali 
Published: October 2017

Abstract
Drilling through a carbonate formation characterized bymassive vugulars and fracturescreates a difficult and high-risk operation when using conventional drilling methods. Total lost of circulation, accompanied byinflux or kicks may be encountered when drilling through high volumes of pores and numerous fracture zones. Using managed pressure drilling (MPD) techniques when drilling through vugs and severely fractured formations can reduce non-productive time in combatting lost circulation problems and preventingformation fluid influxes from reaching the surface during drilling operation. The application of a pressurized mud cap drilling (PMCD) variant of MPD in a recent project in Indonesia was key in allowing the operator to reach their targeted depth.
PMCD is a non-conventional drilling technique designed to maintain annular wellbore pressure when total loss of circulation occurs. With the utilization of MPD equipment and PMCD techniques, mitigation of drilling hazards caused by lost circulation or influx was successfully performed in this project without stopping the drilling operation. The decision of calling out the MPD to the rig site saved the operator drilling days followingunsuccessful attempts to cure the lost circulation by pumping cement for several days.
With PMCD, the proper bullheading sequence was carried outin order to control influxes which weremigrating through the mud-cap to the surface. With applications and actual operations on location, drilling operations successfully reachedthe targeted depth with minimum NPT and optimum hazard and cost reduction.
This paper will describethe planning phase, operational aspects, and results of drilling with the PMCD technique through challenging carbonate formations in a Southern Sumatra oil and gas field.
A Clean and Efficient Development Mode Boosts Community Development and Environment Protection: Development of Keshen Gas Field, Western China
Authors: Jiang Tongwen , Liu Huifeng , Yang Xiangtong , Xu Zhixiong , Zhou Lixia , Wang Kelin , Li Songlin 
Published: October 2017

Abstract
Keshen gas field is located at Kuqa foreland area of Tarim Basin, western China. The surface is mountainous, the environment is tough and the ecosystem is fragile. Through seven years’ development of this field, a natural gas productivity of 5 billion cubic meters per year was obtained by drilling 45 ultra-deep HPHT wells and building a pipeline system of 140km long with zero environment pollution. 41 towns and 4 million residents benefited from this project.
The location of processing plant and pipeline network pattern were selected through node analysis and topology analysis. A fishbone-like pipeline system was selected to avoid the mountainous area and minimize disturbance to the local environment. High-pressure throttling refrigeration technique and high-efficient gas separation technique were also used, reducing the energy consumption for processing by 45%. Electricity was used in drilling instead of diesel, which reduced CO2 emission by 220,000 tons. 140MPa wellhead and 13Cr tubing were used to maintain well integrity. Processing and recycling of oil-based drilling fluids, flow-back fracturing fluids, etc. were also conducted to avoid environmental pollution.
By July 2015, Keshen gas field was successfully established with natural gas productivity of 5 billion cubic meters per year. No pollution to the environment and no harm to the ecosystem occurred. No personal injuries were encountered during 27 million man-hours. A road in the mountainous area which is 108km long was built for the gas field and shared by the local residents. Based on Keshen gas field, a gas supply project was established with cooperation with local government, changing the local fuel type from firewood to clean natural gas, which reduces the annual emission of SO2, NO2 and CO2 by 790 tons, 660.27 tons and 61,500 tons respectively. More than 2,000 job opportunities in the gas field were created for the local Uygur and other minority residents. Totally, 41 towns with 4 million residents benefited from this project. The increase rate of the GDP of Baicheng city was doubled with influence of this project. Not only satisfying the local use, the natural gas produced from Keshen gas field is also transported to eastern coastal cities like Shanghai, Nanjing.
Keshen gas reservoir is an ultra-deep HPHT reservoir with buried depth from 6500m to 8000m, temperature from 150°C to 182°C and pressure from 116 MPa to 136 MPa. With use of many advanced technologies, the reservoir was not only efficiently developed, but with no injuries and no pollution to the environment. It also significantly boosts local community development. It provides a good reference for the development of unconventional reservoirs in the world.
Brownfield Redevelopment Strategies in Offshore North West Java
Authors: Arachman F. , Utami F. , Wasonoaji A. , Tobing D. 
Published: October 2017

Abstract
Offshore Noth West Java (ONWJ) production sharing contract block has been producing since 1970s. The block consists of many oil and gas sturctures, both clastic and carbonate reservoirs. The era of "easy reservoirs" is almost to an end as the fields are maturing over time. Long term development plan is desired to sustain the ONWJ block oil and gas production. The development strategies are focusing on low resistivity development, bypassed oil as the low hanging fruit, add reserves from deeper reservoir and shallow gas development.
Bypassed zones exploitation contributes in sustaining ONWJ oil and gas production. Drill stem test data back from the 70s was revisited, well log and correlation was reviewed to find the proven "low hanging fruit" and possible reserves. Sidetracking well to twin the proven exploration well or simply recomplete existing wells were done to add reserves.
Low resistivity reservoir was considered unattractive or even identified as non-reservoir in the early life of the block exploitation. However, with thourough evaluation and suitable hydraulic fracturing treatment, the reservoir contributes significantly in sustaining production decline. These zones become one of the keys in future development
The gas demand from the near market is continue growing with attractive price. It becomes one of the drivers to find more hydrocarbon gas. In the old days, shallow gas became one of hazard that need to be mitigated. Recently, as the major gas reservoirs continue on its depletion, this shallow was produced; converting from hazard to reserves.
Above strategies were successfully applied within fields in ONWJ block and doubled its production to the level of 43,000 bopd and 180 mmscfd within less than 5 years since operated by Pertamina Hulu Energi (PHE) ONWJ. This paper will discuss subsurface strategies to achieve and sustaining hydrocarbon production and related case studies of several fields in Offshore North West Java. It will also discuss the learning curve for future strategy and application in further redevelopment.
Service Level Agreement: An Effective Communication Flow in the Implementation of Manpower Contract Management
Authors: Hidayatullah Aulia S. , Ismail M. Hasan , Jaya M. Utama 
Published: October 2017

Abstract
There are several parties involved in the implementation of manpower contract management in Total E&P Indonesie (TEPI); the manpower contract personnel, the contractor, Manpower Contract Department (specific department in TEPI who in charge for managing labor supply), and User wherein the personnel deliver their services. Employment issues, grievance or complaint regarding administrative matters may appear in day to day operation which may lead to disruption of work or dissatisfied personnel. However, personnel tend to raise their inquiries to User and Manpower Contract Department (MPC) rather to their real employer, the contractor. As a result, User and MPC will be preoccupied with administration matters and the contractor will have no clue on the ongoing issues. In the present work, SLA 257 is introduced and built to fix the communication flow in this manpower contract management case. By implementing the SLA 257, the effectiveness of communication and problem solving in the implementation of manpower contracts in TEPI have improved significantly. Users and MPC could focus on their operational activities and no longer busy with personnel's questions related to administration matters. In the other hand, effective communication between contractor and their employee impacting to their engagement and personnel satisfactory. In conclusion, the implementation of SLA 257 is not only promoting an effective communication in manpower contract management but also supporting the smooth operational activities in general.
Foam-Assisted WAG: Injection Strategies to Optimize Performance
Authors: Groenenboom Jeroen , Kechut Nor Idah , Mar-Or Assaf 
Published: October 2017

Abstract
Immiscible Water Alternating Gas (WAG) projects can be enhanced by using foaming surfactant in the water slugs with the objective to create viscous foam thereby improving the mobility ratio between gas and the liquid phases. The effective dynamic behavior of foam is complex and dependent on many parameters, such as water saturation, oil saturation, surfactant concentration, and capillary number. Besides the WAG design parameters, such as WAG slug size, and WAG ratio, one should also consider how to time and scale the amount of surfactant to be injected, in terms of concentration and slug size. Part of the dynamics of foam behavior has been calibrated in laboratory experiments showing the effective foam strength in foam scans and its dependency on foam quality (With foam quality defined as the gas volumetric flow rate compared to total gas and liquid volumetric flow rate). Nevertheless, small scale experiments have their limitations and uncertainties remain on field scale performance. Deep down in the formation, factors such as foam strength and stability, and adsorption of surfactant are considered uncertain. These factors call for pilots to de-risk the application further. Simulation studies show that foam strength has a major impact on both ultimate recovery as well as surfactant concentration in the produced streams – stronger foam resulting in lower surfactant concentrations.
The injection strategy also has an important impact on recovery. In some cases, recovery efficiency can be impaired if strong foam is created in the immediate wellbore environment, thereby hampering injection and pore-volume throughput. Sustained injectivity during FAWAG is hence an important component to derisk either in pilots, or lab and simulation studies. This paper demonstrates the impact of different injection strategies and offers some suggestions to mitigate the risk of reduced injectivity during FAWAG.
A Fit of Art of Dynamic Monitoring Technology for Chemical Flooding in Daqing Oilfield
Authors: Liu He , Yang Siyu , Wei Chenji , Yao Zixiu , Ye Peng 
Published: October 2017

Abstract
Daqing oilfield is the largest chemical flooding oilfield in the world. The polymer flooding can enhance oil recovery by 10-15%, while the ASP flooding can enhance oil recovery by over 20%, which is 1.5 times more efficient than the polymer flooding. By the end of 2016, there are 31529 chemical flooding wells, which cover the already proved reserves of more than 1 billion tons. These wells have had cumulative oil production of 0.2 billion tons, and have production more than 10 million tons each year since 2001, thus playing an important role in the production of Daqing Oilfield.
Dynamic monitoring, as an important part for oilfield development, aims to acquire the dynamic and static information in oilfield development, and to provide data for oilfield development dynamic analysis and adjustment by means of testing, logging, coring and analyzing. Since chemical flooding is different from water flooding in oil displacement mechanism, oil-water migration and development process, some indexes in chemical flooding process are especially significant, which are directly related to the development effects, and require timely and dynamic monitoring. Because of the high viscosity of chemical flooding fluids, the monitoring techniques based on the radioactive isotope carrier method of water flooding is not suitable due to problems such as serious contamination and no even dispersion. Therefore, on the basis of tracer monitoring technique for water flooding wells, chemical injection profile logging technique based on electromagnetic flowmeter, oxygen activation and tracer correlation is formed for high viscosity fluids, and has been applied in Daqing Oilfield in more than 4000 wells. This technology could guide dynamic analysis and tracking adjustment, and could have further development of continuous fluid monitoring chemical flooding, and then expand the electromagnetic exploration techniques into the chemical flooding fluid description.
Large-Scale Visual Experiment and Numerical Simulation of Acid Fingering during Carbonate Acid Fracturing
Authors: Li Xiaogang , Chen Yusong , Yang Zhaozhong , Chen Fei 
Published: October 2017

Abstract
While flowing in the fracture, acid may leak off through the wormholes and appear a finger-like pattern during the process of acid fracturing, which is commonly called "acid fingering". Acid fingering is an unsteady hydrodynamic phenomenon that happens when low viscous acid displaces more viscous pad fluid. Many researchers have studied the acid leak-off and viscous fingering, however, there are still many unsolved problems so that the acid fingering has to be ignored, while describing the acid flowing and reaction process.
To solve the discrepancy, a comprehensive study on the moving interface of acid fingering has been conducted with both experimental study and numerical method. Firstly, the laboratory experiments were performed using a self-developed large-scale visual physical device with the structure of three-plates and double-slits, and it perfectly simulated the phenomenon of acid fingering. Secondly, the Volume of Fluid (VOF) equation based on previous large-scale visual physical simulation device has been established and been set up with the similar sizes of it as well. Thirdly, the orthogonal design has been used to analyze the morphologies of acid fingering under the different influence factors, which includes acid type (acid concentration and pad fluid/acid viscosity ratio), acid concentration and acid injection flow rate.
The reasonable agreements between the experimental and numerical results indicate the capability of the finger interface in simulating acid fluid and pad fluid. On the one hand, the acid fingering in the fractures would strengthen the uneven surface etched by contacted fresh acid. On the other hand, this phenomenon will reduce the acid leakage as well as the reaction rate between acid and carbonate rock, consequently improving the effect of acid fracturing. Besides, the acid is more inclined to the flow through lower area under gravity, and the acid fingering would be more significant. Consequently, the finger branches increase, so does the degree of bifurcation.
A combined experimental and numerical approach is adopted to investigate acid fingering in carbonate. Acid fingering could be successfully simulated by large-scale visual laboratory experiment. And numerical method provides a simple but effective way for the operators to predict finger interface under different flow patterns because of low CPU demands and minimal experimental materials requirement of this model, which might reconcile the discrepancy between laboratory study and production practice.