bluuebunny/crossref_metadata_2025 huggingface dataset:
Increasing Working Gas Volume of UGS Based on Low Permeability Lithological Gas Reservoirs
Authors: Zhang Jianguo , Wang Zhenjia , Lan Yifei , Zhao Chenyang , Liu Jinhua
Published: February 2023

Objectives/Scope

A low-permeability lithological reservoir was successfully put into operation in 2015 as a gas storage system. The field S2 Underground Gas Storage (UGS) is located in the Ordos Basin and is primarily alithological trap, with low permeability, high heterogeneity, and no obvious seal boundaries. Based on low permeability, low abundance, low vertical wells productivity, low pressure coefficient, serious skin damage in the bottomhole during drilling and completion, strong heterogeneity and unclear lithological boundaries, low control of injection-withdrawal well patterns, the working gas volume and operating efficiency of S2 UGS underperformed relative to modeled expectations. The technical solutions to improve the working gas volume of S2 USG focused upon: well pattern optimization, well placement, stimulation treatment, infillings, and increasing of operating maximum pressure. The results demonstrate that if reasonable technical solutions are adopted, even poor and low-quality storage reservoirs with low permeability, and strong heterogeneity, can be utilized as natural gas storage targets.

This discussion provides an overview of approaches used in the Ordos Basin to make operation of S2 UGS more efficient. The development of this project, particularly regarding the operation processes and the resulting adjustments, are noteworthy. The development of such UGS reservoirs require new insights into the performance criteria which can be applied to other reservoirs in the future.
High Specific Gravity, Ultrafine Particle Size and Acid Soluble Manganese Tetra Oxide Succeeds in Replacing Heavy Brines as Completion and Workover Fluid
Authors: I.M. El Barrasi Ismaeel Musa , Hale Arthur , Ali Ahmed Mohamed , El Mohandes Mamdouh Atef , Ali Ibrahim Mohamed
Published: February 2023

Objectives/Scope

A high-density completion and workover fluid (18-20 ppg) was required for deep high-pressure gas wells. The traditional clear completion brines, which provide a solids-free environment to run and set downhole completion equipment were evaluated and were not approved as they came with an expensive price tag and, more importantly, they came with serious health, safety, and environmental concerns in addition to formation damage concerns. The available alternative barite weighed water-based mud (WBM) was used as completion fluid to set lower completion; however, due to the concentration and size of the solids contained in this system, serious issues became evident. These included leaks due to poor sealing, string plugging, and stuck completions due to barite settlement issues. Manganese tetroxide (Mn3O4) was evaluated as an alternative to barite as it has higher specific gravity and a much smaller particle size.

Methods, Procedures, Process

To overcome all limitations of brines and barite WBM, and achieve the required density for well control purposes, to address this issue, rigorous lab work was performed to formulate a completion and workover fluid with viscous sodium chloride brine. Additional density was achieved with manganese tetroxide (Mn3O4).

Results, Observations, Conclusions

Manganese tetroxide has a very low SAG index due to its ultrafine particle size. The small size of manganese tetroxide (Mn3O4) eliminated the solids sag and settlement issues that were associated with barite weighed fluid and allowed for longer static fluid periods without the need to interrupt operations to circulate and condition the fluid saving significant time lost on sorting out all barite sagging related issues in previous completion and workover operations.

Novel/Additive Information

This paper presents laboratory design data and comparative data where this type of high-density fluid is used to successfully run lower completions and perform successful workover operations in gas wells without any problems.
A Systematic Approach in Methodology for Permanent Plug Placement in Deepwater Subsea Plug and Abandonment Campaign
Authors: Allapitchai M Shahril Majid , Johan Ahmad Luqman , Liew William Sin Yoong , Sellapan Sattiyaraju , M’Bareck Khalil Ould Mohamed , Ahmad Zaini Ahmad Hafizi , Abdul Razak Mohd Hairi
Published: February 2023

Wells plug & abandonment was carried out in a deepwater field (Field C) offshore West Africa. There were 15 deepwater subsea wells, in this field. Thirteen of the wells were completed with Open Water Vertical Xmas Tree (OXT) while remaining two were completed with Enhanced Vertical Xmas Tree (EVXT). All the wells were permanently abandoned with permanent barriers established in accordance to Norsok D-010, rev 4. (2013). This involved establishing well barriers which would both horizontally and vertically effective. Plug and abandonment in a subsea environment remains a major challenge most operators face around the world. This paper will discuss the systematic approach to establish the methodology for plug placement by Operator for installing permanent abandonment barriers in their campaign.

The paper shall discuss the systematic approach in permanent plug placement as well as highlight challenges and lessons learnts. The paper discusses the guidelines and philosophy to devise methodology for permanent plug placement based on industry capability. The paper also shares the novel approach in devising Plug Placement decision tree as well as well as explanation on principle behind the method. The paper will share on the process flow used by Operator for the permanent abandonment of these wells. Other than that, paper shall highlight the implementation of the decision tree during operations with examples. The best practices and lessons learnts in the plug placement methodology implementation during Operator's campaign in subsea plug and abandonment shall also be discussed in this paper. Ultimately, the paper shall also share on the recommendation for future subsea abandonment planning to assist Operator in their planning.
Application and Performance Monitoring of Compound Air Plasma Lightning Rejection System
Authors: Ho Agnes Yin Yee , Azaman Dzulkarnain , Ahmad Umar Zakir , Chin Han Shen
Published: February 2023

The objective of this paper is to share on the application and performance monitoring of Compound Air Plasma Lightning Rejection (CPLR) system at an onshore terminal facility. Malaysia is one of the top three countries in the world with high lightning density, recorded average of 13.9 flashes per square kilometer annually. Thus, the country's oil and gas industry is indeed vulnerable to the dangerous impact of lightning, often associated with risk like fire, explosion, and release of hazardous material. During the initial stage of lightning development, the air acts as an insulator between positive and negative charges at the cloud and ground. However, when the difference between charges is too great, the insulating capacity of the air breaks down, caused rapid discharge of electricity and resulting in a lightning formation. Upon detection of potential difference between storm cloud and ground, CPLR will release plasma ion, that in theory will neutralize the positive and negative ions and eventually prevent lightning to happen.

This paper will discuss on the investigation outcome of two vent fire incidents at the produced water tanks of an oil and gas receiving facility at east coast of Malaysia, in relation with the functionality of this novel active lightning protection system. Detailed comparison has been made between CPLR lightning rejection data and the data from an electricity utility research company (TNB-Research) lightning mapping to study the system's reliability and effectiveness.

During the first vent fire incident in 2018, data analysis showed that there was no lightning strike within the CPLR coverage area and suspected the lightning propagated from the nearest striking point in lightning mapping following the path of least resistance. In addition, this also surfaced up several installation issues such as insufficient protection coverage due to incorrect pole height design, communication card failure etc. Identified action items have been implemented to restore the CPLR system for tank lightning protection. After that, the system has been closely monitored for its performance and it showed reliable lightning rejection data in year 2020 with no vent fire occurence. However, the second vent fire incident happened in 2021. Post investigation, TNB-R data showed that the lightning stroke 200m from the produced water tank recorded peak current value at −68kA which was two times higher than the average lightning amperage. This concluded that CPLR was unable to reject propagated lightning of high magnitude as well.

In overall, CPLR system is proved to be functioning but with limitation in terms of coverage area and lightning magnitude (kA). With this paper presented, it is expected to complement this novel technology literature with its proof of function, field site installation precautions and as-found system limitations.
Success Journey Designing the First Gas Storage Application
Authors: Fallatah Mohammed , Alsulmi Mohammed , Alhummam Ibrahim
Published: February 2023

The objective of this paper is to shed light on the engineering optimizations and environmental initiatives adopted on Hawiyah Gas Storage facility process design; in order to build a robust facility that would support Saudi Aramco to continue being the industry pioneer and sustainable energy supplier, and meet Saudi Arabia decarbonization targets and minimize environmental footprint.

Hawiyah Gas Storage facility is one of the recent projects built to support the Kingdom energy sector by transforming the power generation industry from crude oil burning to natural gas by addressing the natural gas seasonal supply and demand variation. Eventually, it will enable reducing the greenhouse gas emissions by deploying numerous environmental initiatives, such as attaining lesser fugitive emissions valves, installation of flare gas recovery solution, implementation of relief valves leaks monitoring technology and the installation of ultrasonic gas leak detection systems.

As far for the engineering optimizations; several innovative ideas and case studies were considered in the facility preliminary and detailed design; including the optimization of the Inlet Facility Manifold and the Reproduction Facility Bypass Mode Optimization. The implementation of above-mentioned initiatives had resulted in significant improvements in the facility safe operability, maintainability, and indeed construability at site.

Throughout this paper, the deployed initiatives will be described in details along with the applied methodology to complete the study evaluation, and conclude with the result and discussion.
The Success Case of the Decontamination of Production Sealines in the Gulf of Thailand
Authors: Chanvanichskul Chatawut , Punpruk Suchada , Phanichtraiphop Pheerasak , Silakorn Passaworn , Taksanont Danai , Petchpong Sataporn , Taratapan Peerapong , Sirivikrom Sumet , Sukbanjongwatthana Rittichai , Jinarakpong Suthasinee , Dararatana Naruphorn , Sirithanawuthichai Sukthida , Danthainum Athip , Sillapacharn Thitinun
Published: February 2023

Oil and Gas Pipelines usually contain many contaminants from their long operational services in production. Prior to abandonment of a pipeline at the end of production, the environmental impact due to decommissioning must be assessed in order that the best pipeline decommissioning option, i.e. leave-in-place or by total removal, can be selected. In case of leave-in-place is selected, the decontamination of pipeline shall be performed so that the contaminant concentration is less than an acceptable level. PTTEP have developed own technologies to cover all scopes of decontamination works including contaminant measurement in pipeline since 2015. R&D were performed through technical survey, proof-of-concept, prototype testing, field testing to full deployment to 3 pipelines. The R&D were performed with academic/research institutes, contractors/manufacturers and government bodies. The R&D were divided into 3 main activities: Decontamination Methodology, Decontamination Chemical, Intelligent Sampling Pig.

In 2021, PTTEP commenced the full decontamination using these own developments on three pipeline in the Gulf of Thailand to support the option selection of pipeline decommissioning.

In this report, the summary of the overall pipeline decontamination process including the technology trial of all 3 R&D activities of three pipelines are described.
The Effect of Rock Type on CO2 Foam for CO2 EOR and CO2 Storage
Authors: Sæle Aleksandra M. , Graue Arne , Alcorn Zachary Paul
Published: February 2023

CO2 foam is an effective method to reduce CO2 mobility and improve displacement efficiency in CO2 enhanced oil recovery (EOR) and CO2 storage applications. Foam strength and stability are key parameters that influence the efficiency of the foam which depend on several factors including the presence of oil, injection velocity and rock type. The aim of this work was to evaluate the effect of rock type on CO2 foam strength and stability by conducting corefloods with sandstone and carbonate rocks at reservoir conditions. The effect of injection velocity and the presence of residual oil on the foam generation and displacement efficiency was also investigated.

Steady-state CO2 injections revealed differences in foam generation, strength and stability in sandstone compared to carbonate based on the calculated apparent viscosities. Results showed that the strongest foam was generated in sandstone compared to carbonates because of higher absolute permeability. Drainage-like co-injections with increasing gas fraction showed the relation between rock permeability and the limiting capillary pressure and co-injection at different injection velocities revealed shear-thinning foam rheology in both rock types. Despite stronger foam generation in sandstone, unsteady-state CO2 injections showed similar oil displacement efficiency in both rock types. CO2 foam increased oil recovery by 200% in both rocks compared to CO2 injection without foam. In addition, foam showed a significant impact on water displacement compared to pure CO2 injection which is advantageous for CO2 storage applications. Water recovery during CO2 EOR was 60% in sandstone and 88% in limestone. Dissolution of calcite was observed in limestone, which increased pore space and the CO2 storage capacity. Overall, the results indicate that CO2 foam generation, stability and coalescence are sensitive to rock permeability and pore geometry in the conducted experiments.
Sand Data Acquisition in Gas Terminal: Challenges and Opportunities
Authors: Tuan Mahmud Tuan M Yusoff , T Aziz Tengku Zulfadzly , Myo Thant Maung Maung , C Daud M Faizal , M Johar Juhaida
Published: February 2023

To maximize the hydrocarbon production from wells with sand, the new operating philosophy adopted for sand control. It focusses on limiting production based on the acceptable erosion risk instead of sand production rate. To achieve this, combination of sand production data and laboratory analysis on particle size of the produced sand is crucial. This paper aims to present the challenges and solutions applied for gas terminal sand data acquisition and lab analysis to obtain representative sand data.

A discussion on typical sand acquisition technologies is discussed. The experience from sub-optimal performance within the company are analyzed, the improvement opportunities are identified. Due to the volatile nature of condensate as compared to crude oil, alternative to conventional sampling method need to be applied for gas terminals. Dual particle filtration setup was developed to capture the wider particle range down to 1 micron. The data acquisition was conducted using a closed loop sand sampling system where the outlet of the sampling equipment is connected back to the processing system. To cover the dynamic of sand production, the data acquisition conducted at both normal and pigging operation for 6 hours continuous duration. The collected samples were analyzed using Automated Minerology imaging technology for particle sand distribution and minerology determination

The facility was not designed to receive sand including sand sampling facilities, hence imposed several challenges to acquire the sand data. From the experience during the sampling activity, there are few good observations and lessons learnt from utilizing the innovative approach as follows.

The online continuous sampling allows longer sampling duration without causing interruption to operation. The dual particle filtration ensures as much as possible solid particles that pass through the system will be filtered for analysis. The close loop sampling setup minimizes the exposure of harmful hydrocarbon to the personnel with might contain hazardous contaminant. Sampling that is conducted at different operation mode i.e., normal and pigging will provide wider range of sand PSD and volume.

Due to fines sand, only a small volume of sample was captured at the filter and insufficient for the analysis using conventional LPSA/Dry Sieve method. The recent technology approach via Automated Minerology imaging technology eliminates the issue of limited sample volume.

The experience from the sand data acquisition activity enhances understanding and provides opportunities to explore other sampling technologies/techniques and analysis methods. It is important for the team to assess in totality.
A Systematic Approach to Fault Sealing Capacity Evaluation in Underground Gas Storage: A Case Study from China
Authors: Wang Rujun , Zhou Wei , Zhou Daiyu , Wu Zangyuan , Lian Liming , Yan Gengping , Shao Guangqiang , Zhang Chao , Li Jun , Bian Wanjiang , Jin Quan , Zhao Zitong , Zhang Yong , Deng Yantao , Huang Xingning
Published: February 2023

Fault stability refers to the risk level of reactivation of the pre-existing fault in the stress field. Fault reactivation within the oilfield is mainly caused by the increase of fluid pressure in the fault zone. The quantitative evaluation index of the fault stability is the critical fluid pressure (that is, additional fluid pressure) required for fault reactivation under the current pore fluid pressure. When the formation pore pressure reaches the critical value, the corresponding fault part will be in the critical stress state. The sliding of the fault in the critical stress state will easily cause oil and gas leakage and casing damage at the edge of the fault. Therefore, it is of great significance to study fault stability for oilfield production. Ground stress is a key parameter for fault stability evaluation. There are many methods to calculate the geomechanics including hydraulic method, acoustic emission method, and the use of the logging data, among which the hydraulic fracturing method can be used to obtain the most accurate horizontal minimum principal stress. This paper calculates the continuous geomechanics by using the logging data. There are many methods available for evaluating fault stability, among which fault sealing analysis technology (FAST) method is most widely used. FAST can be used to not only quantitatively evaluate fault stability, but also evaluate the impact of fault cohesion on fault stability. There are many factors affecting fault stability. The relationship between the differential stress and tensile strength of the fault rock will affect the trend of the fault reactivation.The direction of the stress field also affects the fault stability greatly. The argillaceous material weakens the strength of fault rock. When a large amount of argillaceous material enters the fault zone, the fault tends to reactivate. The change of reservoir fluid pressure will also lead to the change of horizontal stress to affect the stability of the fault. In addition, the accuracy of seismic interpretation will also affect the evaluation results of fault stability. Based on the geological model framework and one-dimensional geomechanical model calibration, this paper establishes a three-dimensional geomechanical model by using the finite element simulation method to carry out four-dimensional geomechanical research to evaluate the fault stability in the development of the Donghe 1 Reservoir in Tarim basin. The research results show that the fracture sealing gradually strengthens during the development of Donghe 1 Reservoir, and the quantized critical fracture opening pressure is 67.38MPa.
3D Geomechanical Modelling for Complex Geological Setting: A Case Study from XGS Field
Authors: Luo Yu , Li Long Xin , Zhao Yu Chao , Wang Rong , Younessi Ahmadreza , Zhou Yongsheng , Burns Chris
Published: February 2023

A 3D geomechanical model is built for the XGS field, located in Sichuan province, onshore China. The field is in a faulted anticline consisting of three main reservoir layers. The main reservoirs are in the crest of an anticline structure bounded between major revers faults. The model captures all the structural complexities and the spatial variation of the geomechanical properties and parameters for the entire XGS field. The structural model is built using the interpreted horizons and faults form the surface seismic tied to the markers interpreted from the well data. The 3D grid is constructed for the entire field, extended to the ground level, to use as a framework for the 3D geomechanical model. The well-centric geomechanical models prepared for the 14 offset wells are used in combination to the surface seismic attributes to model the lithology and petrophysical properties for the entire grid. These data are then used to calculate and propagate the geomechanical properties and parameters. The 3D geomechanical model is designed to captures the spatial variation of pore pressure, in-situ stresses, the rock mechanical properties and parameters. The grid has higher resolution in the main target for the underground gas storage (UGS) operation and its immediate overburden caprock layer. This is done to capture and investigate the vertical and lateral variations in the vicinity of the UGS reservoir in more detail. The rock mechanical properties and parameters are dominantly governed by the lithology. This is while the pore pressure and the in-situ stresses are mainly governed by the geological structure. That has been said, a stress contrast is observed between the shale and carbonate layers. The model suggests that the field is in a strike-slip stress regime. The reservoir rock which consists of fractured dolomite is competent and stiff while the shale caprock is relatively weaker. A comprehensive approach is developed to capture the complexities of the structure and properties of the XGS field. A robust workflow is implemented to propagate the geomechanical properties and parameters to maintain their consistency for the entire studied area.
High Pressure 2×2 Screen Development for Extended-Reach, Open-Hole Shunted Gravel-Pack Wells
Authors: Sladic John , Brasseaux Jason , McNamee Stephen , Hodge Robert
Published: February 2023

The industry has a long history of Shunt Tube Technology (STT) used in Gravel Pack operations. The traditional 2x2 configuration of two transport tubes and two pack tubes for long horizontal openhole shunted gravel pack screens worked well for applications upto 1,000 meters, however in the age of extended reach offshore gravel pack wells, modifications to the existing system were required to deal with higher surface pumping pressures, higher screenout pressures, and increased sand placement requirements of the longer extended wells.

The new system was designed to provide the industry a minimum openhole shunted gravel pack length of 1,500 meters based on customer targets. The target design parameters for the high-pressure extended reach system were set at 7,000 psi operating pressure, 150,000 pounds of proppant and a minimum overall gravel-pack length of 1,500 meters.

To achieve this, the existing low-pressure system was evaluated through Computational Fluid Dynamics (CFD) analysis, actual pressure and erosion testing to determine ultimate limitations of the existing architecture. Upon the conclusion of baseline testing, a multi-facetted system improvement plan was developed to create a new system for high-pressure extended reach applications. Areas identified as leading elements for improvement in a long reach high-pressure system were the top rings which divert flow from the transport tubes into the pack tubes at each screen joint, nozzle placement on the pack tube, enhanced nozzle erosion resistance, and the jumper tube assembly with its connectors and seals. Additional improvements to the connector retention system, robust protective split cover, and improved connection dehydration screens would serve to improve run rate, increase RIH durability and improve gravel-pack quality across the non-permeable connection.

After design and qualification of individual pressure retaining components, all system elements were combined, and complete system testing was performed. The system performance testing centered on four test subjects. These were 4-point bend testing, multi-joint erosion testing, multi-joint gravel-pack testing, and rig makeup testing.

This paper will summarize the testing involved in individual component development, system qualification and results of the first field installation.
Efficient Stimulate Long Horizontal Well of Carbonate by Accurately Acid Placement Technology: Case Study from Deep Carbonate Reservoir, Sichuan, China
Authors: Jichuan Ren , Chencheng Guan , Jianchun Guo , Bo Dong , Jie Zeng , Songgen He , Junfeng Wang
Published: February 2023

The length of horizontal wells in deep carbonate reservoir (5000∼6000m) in Sichuan Basin of China has exceeded 2000 meters. Both generating acid-etched fractures and acidizing the dispersed pay-zone are the key to achieving optimal production. The complex conditions of multilayers make it difficult to use open hole packers, instead, sliding sleeves are used in liner completions. However, the layers show strong heterogeneity, which makes it difficult to realize efficient acid stimulation.

This paper presents a technology that stimulates such wells to achieve full acidizing of drilled reservoirs, and optimize the fracturing fluid system and acid-fracturing parameters to achieve longitudinal fracture penetration based on the sweet spot recognition.

Firstly, in order to describe reservoir characteristics and identify sweet spots along the well, an evaluation model was established based on the correlation evaluation parameters of the gas-bearing properties, petrophysical properties, natural fractures, and fracability. The high sweet spot coefficient (HSSC) section and low sweet spot coefficient (LSSC) section were recognized. Then, based on the section classification and the optimal fracture spacing, the position of sliding sleeves is optimized. Sleeves were mainly set at the highest points of sweet spot coefficients in the nearby section.

For different sections, different acid stimulation strategies are proposed respectively. For the HSSC, it is necessary to increase the coverage of acid in the wellbore to realize the efficient acid stimulation of sweet spots alone the wellbore. However, the LSSC sections are mainly caused by the deflection of well, creating artificial fractures and making fractures propagate along the height direction into TL43-3 are needed.

In HSSC sections, the acid coverage increases with the increase of acid volume and injection rate, and it is preferred to use temporary plugging to obtain the wide acid coverage when half of the acid is pumped making the two fractures obtain efficient stimulation with the acid absorption ratio of 1.47 and acid coverage of 207.1m

In LSSC sections, it is still difficult to make artificial fracture break through the upper and lower layers by only use gelled acid even if the acid injection rate is greatly increased. A high viscosity fluid was introduced in acid stimulation treatments could make artificial fracture vertical propagating to break through the upper layers of 16 MPa stress difference with injection rate ≥ 5 m3/min and volume of 100m3.

The productivity of 5 applicated wells increased 66.28%, which proved that the stimulation strategies of HSSC sections and LSSC sections are successful.
First Worldwide Development and Deployment of a Uniquely Designed Blowout Stopper
Authors: Buali Mustafa , Al-Zaid Mustafa , Abdulghaffar Thamer , Gallagher Billy
Published: February 2023

With the increasing challenges in gas well interventions, especially with the need to intervene in wells with extreme sour gases called "high and ultra-high H2S wells," it became vital to have improved safety standards; including, but not limited to, pressure control equipment (PCE). Also, it became necessary to add an extra barrier to shear and seal under any conditions to safeguard against the risk of such toxic release. This improvement and new additional capability have been achieved by developing and successfully deploying a new technology for high risk completion and intervention applications.

This new blowout stopper is an electrically initiated, pyro-mechanical gate valve that performs the critical function of shearing and sealing during drilling, completions and intervention operations. It may be added to the stack or retrofitted to an existing blowout preventer (BOP) cavity. The new BOP is designed to shear anything above the bit and seal instantly even after full flow has been established, with the ability to instantly and reliably stop the release of toxic sour gas regardless of what may be across the BOP. This technology is considered the industry's first true blowout "stopper," as opposed to current "preventers."

The working components of this BOP are isolated from the wellbore fluids before activation to provide unmatched component integrity. In an emergency, such as a work string bottom-hole assembly (BHA) stuck across the BOP, it can shear anything and seal instantly to avert a potentially devastating release of toxic sour gas.

This technology has gone through an extensive qualification program on an international scale. This program was designed to satisfy well control manual requirements, API 16A PR2 and DNVGL-OS-E101. All applicable tests were witnessed and approved by oil and gas well intervention specialists in both the field and yard tests. This paper will describe the technology in greater detail, and talk about the qualification program, including the yard test and first worldwide field trial testing.
Integrated Engineering Solutions for Drilling Extended Reach Multilateral Wells with Lateral Sections More Than 2000 Meters with the Use of Mud Motor. Successful Experience in Tazovskoye Field
Authors: Abaltusov Nikolay , Tensin Sergey , Zibrov Mikhail , Emshanov Anatoliy , Khayvarin Eldar , Sharipov Rafael
Published: February 2023

Rotary Steerable Systems (RSS) are, in general, more efficient versus Positive Displacement Motors (PDM) when drilling the wells under complicated geological conditions. Thousands of operations, performed all over the world, clearly confirm this statement (Wardana, R, 2019). However, this paper will demonstrate that there are geological features where the main advantage of RSS – drilling with constant rotation – is not efficient and may result in emergency situations.

Specifically, under such geological conditions it is necessary to drill in Tazovskoye field which is developed by extended reach horizontal and multilateral wells.

This paper will cover integrated engineering solutions, which made it possible to overcome geological challenges to reduce the costs of drilling extended reach multilateral wells by a deliberate engineered change from RSS to PDM application.

The approach was confirmed in 11 multilateral wells, drilled with the use of PDM. In this case the length of each horizontal hole totaled 2000 meters and more.

An all-time record was achieved in Russia in terms of the length of horizontal wells, drilled with PDM motors without using oil-based mud: a horizontal section 2,520 meters in length with DDI – 6.72, ERD – 2.67 was drilled.
Application of Fracture Propagation and Production Simulation Technology to Multi-Stage Length Optimisation in Horizontal Wells
Authors: Ding Xiaojun , Zhou Wei , Bai Jinlian , Yuan Dongjiao , Lian Liming , Chen Jinghua , Zhao Haizhu , Li Xianming , Yang Xiao , Deng Yantao , Huang Xingning
Published: February 2023

Low-permeability reservoirs are characterized by low oil and gas abundance, poor permeability, natural productivity lower than the lower limit of industrial oil flow, and rapid decline of formation energy. Hydraulic fracturing technology is widely used for the development of low-porosity and low-permeability reservoirs. The hydraulic fractures formed by using the hydraulic fracturing technology are the "underground highway" for oil and gas flowing from the deep reservoir to the wellbore. The combination between the long well section of the horizontal well in the reservoir and the wellbore can greatly improve the utilization of oil and gas resources in the reservoir. Therefore, hydraulic fracturing is the key technology to improve the production of low-permeability reservoirs. This paper establishes a volume fracturing propagation model by using the finite element method and discrete element method, and conducts the fracture propagation simulation of multi cluster fracturing in horizontal wells of low-permeability Nanyishan reservoirs in Qinghai Oilfield. The results show that when the stress difference (Difference between the maximum horizontal principal stress and the minimum horizontal principal stress) is less than 4 MPa, volume cracks tend to be generated. When the stress difference is higher than 5 MPa, plane cracks are mainly generated. The natural fracture density affects the volume fracturing effect only under the condition of low stress difference. When the stress difference is 3 MPa, the number of perforating clusters is increased, the cluster spacing is reduced, the improvement area is not significantly increased, the cracks between clusters are seriously interfered, and local cracks are merged. When the stress difference is 5 MPa, there is relatively weak interference between clusters. The increase of perforation clusters promotes the communication between natural fractures, volume fracture development, and expansion of reconstruction area. The research results of this paper provide strong technical support for optimizing the fracturing scheme, improving the single well productivity of low-permeability reservoirs, and developing low-permeability reservoirs in a cost-effective way.
Innovative Fireproof Insulation for Safe Operation of Non-Metallic Pipe
Authors: Jinarakpong Suthasinee , Punpruk Suchada , Kumseranee Sith , Sanitmuang Thirawat , Rattanasombattawee Nopphan
Published: February 2023

Reinforced Thermoplastic Pipe (RTP) is one of the solutions considered using instead of metal pipe to avoid the corrosion problem. As RTP is a non-metallic pipe that is subjected to damage or deformation when get fire. A protective fireproof system is required to protect RTP from cellulosic fire for at least 2 hours. and pipe surface temperature not over 82 °C per RTP specification and should be reusable and has a long service life.

From the performance test results, there are two materials of PFP (Passive Fire Projection) that passed the requirement. One is intumescent (Composite fiber glass fabric with external polyurethane "PU" coating 0.7 mm.) and the other one is rockwool insulation (Reflective heat guard 3 mm. + Rockwool insulation 50 mm. + Aluminium 1 mm.). The rising of the surface temperature of the Reinforced Thermoplastic Pipe (RTP) is in the acceptable criteria. The RTP pipe appearance is still in good condition. For PFP appearance, the intumescent will be damaged after burning while rockwool insulation is not changed and is reusable. In terms of material cost, the price of intumescent including material cost and installation cost is lower by about 20%. Both options are interesting and shall be considered again for usage purposes. Replacement of metal pipe with spoolable pipe with PFP has advantages in terms of low maintenance cost and higher corrosion resistance. The Reinforced Thermoplastic Pipe with PFP can be installed on existing pipe support with enough space for inspection. This solution can eliminate the weak point of RTP and allows the application of RTP without pull through carbon steel pipe. The PFP rockwool insulation is a good option to protect pipeline damage from unpredictable fire with low material and installation costs.
New Hybrid Technology and Sensing at the Bit Sensors Utilized in Directional Applications at North to Kuwait to Help to Identify and Minimize Disfunctions
Authors: Pan Yi , Vrnak Kyle , Fierro Juan Carlos , Shehab Meyar , Arora Saurabh , Al-Mutawa Faisal , Al-Barazi Nasser
Published: February 2023

Access to develop new drill bit technologies are increasing the capabilities to improve performance in the most challenging directional applications, where the focus is to reduce any type of disfunctions that will be generated due to the interaction between the drill bit, drill string and formation compressive strength. A case study is presented to demonstrate the liability and consistency of this new technology.

This paper discusses the sensing at the bit technology that has different capabilities that can be used to improve drilling performance, combining the new cutting structure in the drill bit that keeps in series the shearing and breaking actions generated by the new cutting elements, at the same time those actions are recorded by the drill bit sensor. The generated information is used to compare standard drill bits with modified designs where the advantages can be seen clearly, and at the same time new engineered technologies can be put in place to have further improvements in performance.

In Kuwait, the 12 ¼" section is a challenging application in terms of directional requirements, rate of penetration and is mandatory to have the necessary stability to be able to increase the required drilling parameters that will end up with outstanding performances.

A compressive engineering analysis of a customized drill bit and the implementation of the sensing at the bit data capture was used to understand the drilling parameters, drilling disfunctions and the interaction between the engineered cutting structure and the formations drilled. The data was correlated with available data from offset wells and helped to confirm the performances achieved. The detection of different disfunctions and the frequency generated for the added device was the key to understand the functionality of the tool. It showed that the new technology drill bit, in which a rolling crush-and-shear cone is incorporated to the center of a PDC bit, increases bit stability and mitigates lateral vibration while achieving outstanding performance.
Chemical Sand Consolidation and Through-Tubing Gravel Pack, the Effective Alternative Sand Control Methods in Zawtika Field
Authors: Peerakham Chatchanakorn , Haripogepornkul Nopparerk , Putthaworapoom Natthapon , Direkmahamongkol Suwit , Thanasutives Patana , Zin Ko Ko Thaw , Lin Tun Zin
Published: February 2023

Sand production has been highlighted as one of the critical challenges for Zawtika Project. Throughout the years of field experiences, sand production management has brought up many challenges, especially in terms of field potential sustaining, well productivity and investment justification. Alternative sand control technique is one of the keys to overcome these challenges with continuous improvements driven by lessons learnt.

Chemical Sand Consolidation (CSC) is the chemical sand control technique using the resin to bond the formation grain and strengthen the formation strength whereas Thru-Tubing Gravel Pack (TTGP) is retrofit sand control method, which the sand control principle is similar to conventional Cased-Hole Gravel Pack (CHGP), but can be installed in a smaller completion size. In Zawtika existing development phases, almost 150 zones of sand producing intervals are handled by CHGP completion design. In addition to CHGP, these mentioned alternative sand control techniques have been successfully implemented in 3.5-inch-tubing monobore completion for selected deep reservoir intervals after some degree of depletion.

Field trial of CSC and TTGP had been implemented during 2019-2020 with 5 reservoirs in 7 monobore completion wells (4 CSC wells and 3 TTGP wells). All wells showed positive results with no sand production from the post-job production; and with a reasonable increase in Maximum Allowable Sand Free Rate (MASR). Based on well performance monitoring until early of 2022, all 3 TTGP wells as well as 3 CSC wells no longer have any sand production issue. Nevertheless, only 1 CSC well with water production history record prior to CSC implementation shows poorer performance on sand production prevention.

Following the positive results of TTGP from the previous campaign in term of sand production prevention and well life extension, 8 more TTGP well candidates have been implemented in early of 2022. At the early phase of production, sand free production has been observed for all wells with 51 mmscfd incremental MASR.

With all aspects of technical and fiscal evaluation proven to be successful, sand retention and production performance of CSC and TTGP are continuously monitored to confirm long-term performance efficiency for full application in the future.

Zawtika sand management strategy through alternative sand control completion has been improved upon accumulated lesson learns and production experiences. The lesson learns and experiences from both operation and well performance monitoring will be integrated for further improvement for the next implementation phases. Maximizing gas potential through alternative sand control methods is also believed to be the cost-effective approach which strengthens PTTEP's competitive performance.
First Implementation of Ultra High Compressive Strength 12.5 ppg Cement Slurry in Production String in Kuwait Oilfields
Authors: Thanaa Mohamed , Almihdawi Anwar , Lopez Ezequias , Fadtare Ashish , Ansari Mohammed Fauzan , Al-Shammari Altaf , Al-Failkawi Khaled , Al-Khaldy Meshal , Hussein Ahmed , Majeedkhan Pattan Kp , Khamis Mohamed
Published: February 2023

Quality Cementation across production sections consisting of depleted/weaker formations is the main challenge in Kuwait. Usage of conventional cement slurry over 15.8 ppg will lead to losses and poor zonal isolation. Newly designed 12.5 ppg enhanced compressive strength cement slurry was proposed to achieve desired zonal isolation and well integrity while avoiding losses and unnecessary remedial jobs.

Strategy was formulated to minimize exposure of weaker formations for higher ECDs during cementation. Conventional 15.8PPG tail slurry was replaced with 12.5PPG Ultra high compressive strength (4000psi) cement slurry. New slurry design helped to carry out cementation job without any losses while achieving rapid compressive strength and excellent cement bond across production casing. The technology is based on three radical changes in the conventional way of designing cement Slurry of Substitution of part of the cement volume with inert agents of low specific weight, High packing density using solids of different sizes, and Reduction of water volume required.

The job was performed safely and successfully, no losses was observed during and after the cementing job while getting pure cement returns at surface during both stages of cement job. CBL/VDL was performed 24 hrs after the cement job; and the results were excellent. The main advantages of this technology are: Ø High resistance to compression: Once the slurry has set, it is capable of developing compressive strength values ​​similar to heavier conventional slurry. Ø Low reactivity: Most of the elements used are chemically inert, this facilitates the design of the slurry by reducing adverse chemical reactions. Ø Low Shrinkage of Cement: Due to the reduction of the volume of the Portland cement in the slurry, the shrinkage of the set cement is reduced, which allows a better adherence of this to the formation and to the Casing. Ø Mix-ability: Does not require special equipment for its preparation, as if foamed cements require it.

Three case histories will be presented with all data and evidence, showing design phase, planning phase, execution phase and results obtained with all logs were showing the excellent results were achieved. This technology has several applications in the industry, which can be executed satisfactorily.
Evolution of Power Generation of Offshore Wellhead Platform to 100% Solar Power System Design
Authors: Kurustien Wiwat , Maneeanekcoon Taweepong , Chaiwiboonpol Pisit
Published: February 2023

Regarding the Direct Current (DC) power generation for the offshore gas wellhead platform, the hybrid power generator Thermoelectric generator (TEG) and Solar Panel is used in the COMPANY design to supply power for DC loads such as a PLC and Telecom system of the offshore gas wellhead platform in past 10 years.

To effectively achieve Capital Expenditures (CAPEX), and Operating Expenditures (OPEX) and green environment, now 100% solar panel power generator with battery backup is considered. The challenge of a single power generation which is a solar power system is reliability. There are a few key factors that effect to the reliability of 100% solar power system design. The shadow on solar panel, solar radiation and battery backup duration during the low insolation and nighttime would be key factors in engineering design.

Approximately 20 gas wellhead platforms in the gulf of Thailand are designed with 100% solar power generation with battery backup during the past 3 years, they have been operating without power generation issue. When designing solar panel locations, the software Sun-Path software is used to confirm there is no significant shadow on solar panel in all seasons. For the sun solar radiation, we use weather statistic solar insolation data provided by NASA. And battery backup time, we use weather statistic data as a factor for battery backup time. During the low insolation days and nighttime, the DC load shall be power supplied by backup battery. Battery duration shall be referred to solar insolation and Equivalent Number of NO-SUN Or BLACK Days data provided by NASA.

As per a study prior deciding to select 100% solar power system gas wellhead platform, 100% solar power system CAPEX can totally save about 30% when compared to Hybrid Thermal Electric Generation (TEG) &Solar power generation. In addition, there is no concern about fuel gas properties such as high CO2 on wellhead platform. There is no fuel gas consumption in solar panel power generation which support a green environment.
O juiz, os comissários de menores e os “morcegadores” (Recife - décadas de 1960-1970)
Authors: Miranda Humberto Silva
Published: February 2023

Debruçar-nos sobre o acervo do periódico Dário de Pernambuco fez com que nós encontrássemos uma série de reportagens sobre o cotidiano de meninos e meninas em situação de pobreza, abandono ou em conflito com a lei. Entre as matérias, foi encontrada a reportagem que noticiava a atuação do juiz de menores do Recife, Nelson Ribeiro, intitulada Recuperar os menores é o lema do Judiciário. A partir da análise do discurso dessa matéria, intercruzando-o com outras fontes documentais, objetiva-se neste texto problematizar como foram produzidas as formas de controle social sobre as crianças e adolescentes em situação de abandono, no período marcado pela implantação da Política Nacional do Bem-Estar do Menor, que entrou em vigor meses depois do golpe civil-militar, em 1964. Nesse processo argumentativo, será discutida a atuação dos comissários de menores e a produção discursiva sobre a “questão do menor”, artindo do argumento de que o juizado de menores buscou atuar a partir da lógica policialesca. Dessa forma, procuramos analisar como foi construída uma governamentalidade sobre o problema social historicamente produzido, no período em foco, quando a “questão do menor” passou a ser concebida como uma “questão de segurança nacional”.