bluuebunny/crossref_metadata_2025 huggingface dataset:
Successful Delivery of Slim Well Design Concept for Future Marginal Fields
Authors: Abu Bakar Nurul Nadia Ezzatty , Hod M Aizat Haidi , Abitalhah M Abiabhar , Omar Ahmad Faiz , Abdul Hakim Hazlan
Published: March 2022

This paper will discuss the key focus areas in successfully delivering a slim well design as a Proof Of Concept (POC) for marginal fields and well cost optimization.

Well Tall-A is a Near Field Exploration (NFE) well targeting marginal reservoir which utilize the slim well concept; a 2-hole section well with 9-5/8" as the conductor. For a successful well execution, three (3) key focus areas were identified which are successful operation of 9-5/8" Casing While Drilling (CWD) to section TD, sustainability of 9-5/8" casing as conductor for the whole well life cycle and achievement of well objectives.

Tall-A recorded the longest and successful 9-5/8" CWD Level 2 (non-directional) for Asia Pacific with 1168m drilled footage as of year 2020. Lessons learnt from previous PCSB 9-5/8" CWD operation were incorporated for casing bit selection hence a heavy-set casing bit (8 bladed) which has been proven in drilling long hole interval in the Middle East (>1000m) was utilized. Continuous monitoring during execution is essential in ensuring the casing is set at the desired setting depth. Sustainability of the 9-5/8" casing as conductor for the whole well life cycle is critical for a slim well design concept. Several studies and extensive discussions between multiple parties has been incorporated to enable utilization of the 9-5/8" as conductor with required sufficient tension to sustain the exploration well lifecycle. A conductor study was performed which incorporated the Metocean data, rig data and connection Stress Concentration Fatigue (SCF) to qualify the 9-5/8" as conductor. To meet the primary and secondary targets; the 8-1/2" hole needs to be kicked-off early and build up to maximum 44 deg before maintain tangent to final TD at 2752m MDDF. Due to the long open hole (1475m) and well inclination within the avalanche hole cleaning regime (30 to 60 deg), the well is prone to hole cleaning problem and wellbore instability. Hence, it is critical to have good drilling practices and precise mud weight selection to ensure no hole problem encountered. The well was successfully drilled to TD, completed the well testing and P&A.

In summary, well Tall-A successfully maneuvered all challenges to deliver the well safely that resulted in Best In Class (BIC) performance. The slim well design concept has been proven achievable and serve as base design for future marginal wells.
Qualification of Cost Effective Mechanically Lined Pipe Solutions for Reel-Lay Installation
Authors: Jones Richard , Toguyeni Gregory , Suhaimi Radzlan Ahmad , Banse Joachim
Published: March 2022

The use of mechanically lined pipe (MLP) for both flowlines and risers installed by reel-lay is well established, giving significant cost and schedule benefits relative to conventional metallurgically clad pipe. Successful offshore installation of MLP is underpinned by comprehensive qualification testing. Evolving MLP products, including the use of thin liners and adhesively bonded MLP, i.e. GluBi®, continue to improve the competitiveness of this linepipe product. The paper will highlight the key steps for qualification, including new products, the lessons learnt captured during fabrication and installation as well as the benefit of a local spool base for the Asia Pacific region.

Subsea 7 has worked in close collaboration with leading supplier Butting to perform the qualification of MLP. The latter, initially, comprises extensive non-destructive and destructive testing of the linepipe materials including the liner/ weld overlay interface. Subsequently reeling test strings are fabricated using qualified welding solutions. Internal visual inspection and dimensional measurements are carried out using laser metrology to provide a benchmark for comparison post reeling. The test strings are given a simulated reeling procedure using bending and straightening formers, representative of Subsea 7's installation vessels. The internal pressurisation technique, as per standard installation practice for MLP, is applied during the simulated reeling procedure. The need for internal pressurisation is eliminated in the case of adhesively bonded MLP. Post reeling the internal laser metrology inspection procedure is repeated to confirm the integrity of the liner and to check for the presence of any evidence of liner wrinkling or damage. Subsequently, for riser applications, full-scale fatigue testing is performed using the high- frequency resonance bending procedure with a focus on the integrity of the junction between liner and weld overlay or, as commonly termed, the triple point.

Additionally, finite element analysis (FEA) is often performed to further validate the satisfactory reeling performance of the MLP. All the qualification activities are carried out and verified in alignment with DNV-RP-A203 Technology Qualification (Ref.1)

To date Subsea 7 has installed several hundreds of kilometers of MLP flowlines and risers, with pipe NPS in the range 7" to 14" and including 316L, Alloy 825 and Alloy 625 liners. This thorough qualification process and experience combined with the successful set up of a regional spool base provides a robust and cost-effective alternative to the conventional metallurgically clad pipe.
The Journey Towards a Net-Zero Emission Future
Authors: Venkatesh Suresh
Published: March 2022

The recent trends indicate strong growth opportunities in the FPSO market. Securing financing for projects, however, will continue to be a challenge – given the rising expectations of the investment market.

This paper presents a methodology to address demand for climate-related information by investors. It provides practical guidance to build a robust framework – to boost environmental credentials, enhance investor and lender confidence and improve access to capital.
Early Stuck Detection Using Supervised and Unsupervised Machine Learning Approaches
Authors: Inoue Tomoya , Nakagawa Yujin , Wada Ryota , Miyoshi Keisuke , Abe Shungo , Kuroda Kouhei , Nishi Masatoshi , Bilen Hakan , Mopuri Konda Reddy
Published: March 2022

The early detection of a stuck pipe event is crucial as it is one of the major incidents resulting in nonproductive time. An ordinary supervised machine learning approach has been adopted to achieve the detection of stuck pipe in some previous studies. However, for early detection before stuck occurs with this approach, there are challenging issues such as limited stuck pipe data, various causes of stuck, and the lack of a prior exact "stuck sign" which should be a label in the training dataset.

In this study, the surface drilling data is first collected from multiple agencies to enhance the training dataset. Subsequently, a supervised machine learning algorithm with ordinary binary classification methodologies, such as support vector machines and neural networks is adopted. The supervised machine learning approach presents good performance for stuck pipe event detection. However, it detects "stuck has already occurred", and it cannot effectively predict the stuck pipe because there is no exact sign for stuck pipe which is mandatory as label for training data.

This study also adopts an unsupervised machine learning algorithm which employs architectures that include an autoencoder with long short-term memory, as well as a multiple prediction model to improve the expressiveness. The unsupervised machine learning process typically involves learning the features of normal activities, whereby the created model can represent only these activities. When stuck occurs or will occur, as such data are not represented by the created model, it should be detected.

The performance of the early stuck pipe event detection using supervised and unsupervised machine learning approaches is analyzed, and the results demonstrate that the unsupervised machine learning approach presents a better early stuck pipe detection capability. The proposed machine learning algorithm will be further improved in the future and the prediction result will be validated through actual operation.
An Electrifying Integrated Solution Towards a Safe and Environmentally Sound Well Abandonment in Urban Setting
Authors: Mohamad Syah Imran , Joppe Lambertus Carolus
Published: March 2022

In the Netherlands, a large number of onshore wells are near urban areas or close to forests where environmental emission and noise reduction are important to consider. With more than 23 different well site locations to be abandoned, a significant amount of collaboration is required to ensure there is minimal interruption and impact to the local community and the environment.

To achieve this, the operator together with Baker Hughes as the project management lead, formulated a unique, low-impact solution with fully electrified equipment that mostly uses grid power. Alongside other service partners, the majority of the onsite equipment are electrically driven, such as the rigless well abandonment unit, cement pumps, ancillary equipment, and the slickline unit. A noise dampener and decibel readers were put in place to minimize and track sound emissions.

Such collaboration and integration with all providers were carefully identified and mitigated through a series of non-technical risks (NTRs) to ensure compliance with local regulations. Extra steps were taken to ensure that smell and noise remain unnoticed by the surrounding environment. Frequent communications are sent to the public by the operator to keep everyone informed prior to any mobilization.

After a one-year campaign, there have been zero LTI, zero accidents, zero non-compliance incidents and above all, safe and secured end-of-life oil wells in an urban setting with many more to follow suit.

This paper will provide insight into the integrated operations of a well abandonment project in a unique urban setting and the challenges to successfully abandon wells of varying complexity. This project is to be accomplished in compliance with the local mining and environmental regulations with no remaining liabilities, all while limiting total project costs. The supply chain stepped up by providing a cost-effective solution through multi-party collaboration, multi-skilling, technology innovation, and logistical solutions. The project planning, start-up phase, and an overview of the first year of operations will be presented.
Laboratory Investigation of Hybrid Nano-Assisted-Polymer Method for EOR Applications in Carbonate Reservoirs
Authors: Zhangaliyev Medet Maratovich , Hashmet Muhammad Rehan , Pourafshary Peyman
Published: March 2022

Currently, there has been a surge in evaluating the effectiveness of various hybrid enhanced oil recovery (EOR) methods as they combine the benefits of standalone processes. This study focuses on laboratory investigation to evaluate synergy between polymer and nanoparticles (NP), as their combination can simultaneously alter capillary and viscous forces.

N-vinyl-pyrrolidone-based partially hydrolyzed polyacrylamide and silica oxide nanoparticles are used in this study. The standalone polymer, nanofluid (NF), and combined polymer-nanofluid solutions are prepared in different salinities (1200-40,000 ppm). The zeta potential of solutions is measured to determine the stability of NF at various salinities. Contact angle measurements are performed to determine the optimum concentration of NP. A series of rheological experiments are accomplished at different nanoparticle concentrations (0.05, 0.1, 0.15 wt%), temperatures (25-80 °C), and polymer concentrations (500 to 3000 ppm). Additionally, a long-term stability test was conducted over thirty days at 80°C on nano-assisted-polymer fluid over a long period.

Zeta potential results proved that the stability of nanofluids decreases with an increase in solution salinity. However, the addition of polymer has a positive impact on the stability of NF and is stable up to 40 000 ppm salinity. The nanoparticles have shown potential in altering the wettability of the rock toward the intermediate wet conditions. A maximum deviation of 55° in contact angle is observed for a 0.1 wt% NP solution and is selected as optimum concentration. Rheology studies illustrate that the addition of NP increases the viscosity of the polymer solution by 25%. All nano-assisted-polymer solutions tested in this study showed shear thinning behavior. Long-term thermal stability of nano-assisted-polymer solution indicates that the solution achieves equilibrium after 5 days and maintains target viscosity of 4 cP.

The addition of polymer has positively impacted the salinity tolerance of nanoparticles. Additionally, nanoparticles improved the viscosity of the polymer solution. This study will open new doors for the hybrid EOR method.
Automation in Cuttings Analysis: Futuristic Preview of Digital Enablement for Geology 101
Authors: Shrivastava Chandramani , Bondabou Karim , Ammar Mahdi , Santo Simone Di , Yamada Tetsushi , Androvandi Sophie
Published: March 2022

Analysis of drill-cuttings collected on the rig has always been the most basic, yet most direct means of understanding the subsurface within its own limitations. However, automation enabled by digital transformation of this aspect of mud logging has greatly increased the importance of this data. A futuristic preview is being presented for the repositioning and value showcasing of most basic and widely available data, i.e., cuttings with digital enablement.

Cost-efficient characterization with lean sample preparation, reducing the adverse environmental imprint to near real-time formation evaluation leading to enhanced well placement and completion design is reshaping the old-school mudlogging with direct detection and quantification of minerals, total organic carbon (TOC), kerogen content and elemental composition; often minimizing the requirement for time-and-cost intensive wireline logging. Labor-intensive sample collection is getting automated, and subjective and descriptive interpretation per experience of mud-logger is giving way to digital, objective interpretation, ready to be integrated with logging-while-drilling data in real-time.

In addition to the X-Ray Fluorescence & Diffraction; newer technologies like Diffused Reflectance Infrared Fourier Transform Spectroscopy (DRIFTS) are being incorporated in wellsite set-up with reduced footprint on rig and minimized usage of chemicals. Unique automated process can analyze high resolution digital images to deliver plethora of information in minimum time; often augmented with the help of artificial intelligence. A futuristic view with building blocks of the automated interpretation process is presented.

Examples from different steps needed to achieve automation are provided, from sample preparation to digital analysis through machine learning for a holistic futuristic vision to highlight digital enablement in delivering the well-objectives in cost-efficient and timely manner honoring the changing market dynamics. This foundational cutting analysis (Geology 101) vision would drive further adavnces in this field.
A Risk Based Approach for the Integrity Management of Single Point Mooring Systems
Authors: Isnadi Biramarta , Mahasan Suhaimi , Omar Syahnaz , Fazli W Hariz , Sahari Yusuf , Suhendra Ave , Wong Ellis , Kamaruzaman Aiman , Khan Riaz
Published: March 2022

This paper describes the SPM Integrity Management approach using risk based strategies for Single Point Mooring (SPM) throughout its asset life cycle, to ensure that there is a structural integrity management processes are implemented and SPM asset fitness for purpose is always maintained. SPM is one of the most important assets for any oil and gas upstream business, as its primary function is for product export and offloading operations. PETRONAS UPSTREAM currently operate seven (7) Single Point Mooring (SPM) assets for its Malaysia Upstream/ Downstream. To manage the integrity of the SPMs, an Integrity Management system has been developed and includes newer assets and those that are approaching or exceeding design lives.

To optimize and focus limited resources toward critical activities, a SPM risk-based strategy and methodology for the SPM assets has been developed. The risk based inspection approach is aligned with the Structural Integrity Management (SIM) processes of DATA, EVALUATION, STRATEGY PROGRAM of the API RP2SIM code of practice. A qualitative risk based integrity management has been developed and for its implementation, inspection and maintenance activities shall target high expenditure items. SPM design, characteristic, assessment, and inspection data have been compiled and utilized in the risk based approach development.

With this risk-based approach, PETRONAS can optimize and significantly reduce its inspection and maintenance activities whilst keeping operational risk levels within acceptable limits. The risk-based approach provides that added advantage to look at inspections and maintenance activities critically and make informed decisions on resourcing and aligning inspection & maintenance campaigns for the future.

Inspection and maintenance measures also include an anomaly management, RBI, data management and inspections scopes of work which are being digitized and maintained within the Company's Structural Integrity Compliance System (SICS).
Direct Hydraulic Control Systems as a Key Enabler for Developing Shallow Water Marginal Fields
Authors: Hammond Steven , Zahari Iman , Berwanto Awaluddin
Published: March 2022

Objectives/Scope

In the current situation of the industry, high numbers of prospects are being considered as not economical to develop due to various factors including low reserves, high complexity and stranded locations with no suitable host facility to tie-in to nearby.

This paper will discuss how the utilization of direct-hydraulic subsea control technology, when coupled with shallow water tree technology, can be deployed to enable technically and commercially viable solutions for marginal shallow water fields.

Methods, Procedures, Process

Under these circumstances, direct hydraulic technology has a number of advantages over traditional EH-MUX control systems, such that direct hydraulics can enable the development of fields which would otherwise be uneconomical.

These advantages include –

Results, Observations, Conclusions

By using Direct Hydraulic technology, the project was able to achieve a commercially attractive and technically fit-for-purpose design, leading to successful project sanction (the first such project in Malaysian waters), and opening the door for similar future developments to follow.

Novel/Additive Information

This paper will present information and methods that will be of benefit to other Operators in the subsea industry who are seeking to unlock reserves that are currently in marginal fields and would be uneconomical to develop using other methods. The benefits that can be gained are both in terms of proof of concept using off-the-shelf designs, and opening up otherwise uneconomical fields for development. In this particular case, the project opens up a further 6 new fields which were previously considered uneconomic to develop.
Flow Assurance Testing with Re-Livened Oil: A Cost-Effective Analogue for Live Oil
Authors: Farrell Andrew Robert , Ewing Andrew , Frigo Dario Marcello , Graham Gordon Michael
Published: March 2022

It is widely accepted that live crude oil samples provide the most field representative fluids when investigating asphaltenes and paraffin wax problems in laboratory testing. However, this approach is limited by availability of live samples and the potential that samples collected during drilling will be insufficiently representative due to contamination. This paper demonstrates that re-livened oil comprising dead oil and just 1 or 2 solvents can be an acceptable replacement where live oil of sufficient quality is not available.

We outline a best-of-both approach: using readily available dead oil but replacing the volatile ends with components that reproduce much of the solvating and phase behaviour of live oil, and where they differ from it, they do so in a predictable manner, which can be readily modelled using an equation of state (EoS) simulator. This avoids the expense and time required to restore the oil to a precise replica of live fluid while still generating laboratory data to increase confidence in predictions for the actual live oil composition generated by the EoS software.

Illustrative examples are given to demonstrate different ways in which re-livened oil can be designed to mimic key features of live oil behaviour, and any differences can be modelled. Wax appearance measurements were made for re-livened oil and used to calibrate an EoS model. When used to simulate data for a live oil, the calibrated model gave excellent agreement with field data. Subsequently, deposition tests were carried out with re-livened oil and used to qualify a wax inhibitor for subsea application. Measurement of the Asphaltenes Onset Pressure (AOP) for re-livened oil was used to tune the EoS model for the analogous live oil, yielding predictions of the asphaltenes precipitation envelope (APE) that were consistent with those obtained using the live oil. This illustrates that live oil may not always be necessary to obtain a reliable APE, especially when the only live oil samples are of questionable quality. Solubility theory was applied to the selection of conditions for asphaltenes flow-loop deposition, wherein a precipitant is added to dead oil to induce deposition. This approach can determine both the identity and correct proportion of a suitable precipitant to simulate conditions close to the bubble point where deposition commonly occurs.

Our work shows how experimental results (both laboratory and field) were used to validate the methodology presented here. The findings of our work will lead to significant cost-savings in performing both flow assurance risk assessments and inhibitor qualification. Rather than going to the significant expense and operational difficulty and risk of collecting and transporting live samples, such screenings can be performed on re-livened fluids that are both field representative and cost-effective.
Integrated Online Emulsion Management System
Authors: Hon Vai Yee , Halim Nor Hadhirah Bt , Panuganti Sai Ravindra , Chai Ivy Ching Hsia , Saaid Ismail B M
Published: March 2022

A full suite of integrated online emulsion management system (IOEMS) transforming the handling of decades old crude oil emulsion production issue at field from reactively onsite to proactively online. This technology is made possible with insights on emulsion formation from physics-based molecular models, access of huge database on crude oil properties, emulsion toughness and demulsifier chemistries, coupling with statistical and supervised machine learning application.

Intriguingly, this innovation journey began with designing an enhanced oil recovery (EOR) technology in mind. Study on generating stable emulsion for oil recovery was the aim of our pioneering research initially. We successfully developed physics-based models to assess emulsion stability at molecular level. We then applied these models retrospectively for produced emulsion management, with advancement in data science and computational power. The technology concept is to design and plan demulsification strategy based on predicted emulsion stability. The robustness of IOEMS lies in the combination of the goods of accurate interpolated data based on machine learning, with that of extrapolated data from physics-based model. Firstly, mathematical models of relationships between crude properties and emulsion stability index (ESI) were established using statistical method. This led to a good 90% match with laboratory ESI data. Secondly, a demulsifier selection functionality was developed based on machine learning, covering dozens type of demulsifier. We used operating conditions, fluid and demulsifier properties as training data input, with the corresponding lab bottle tests outcomes as training data output to build a classification model via supervised learning algorithms. Its predictive accuracy is at 87%.

By bringing the produced emulsion assessment from on-site to online, offshore emulsion sampling and the associated lab bottle tests are minimized. Health safety and environment (HSE) risks are reduced accordingly with the decrease of human intervention in field sampling. The emulsion stability predictive functionality enables operation to prepare early in anticipation of sudden spike of emulsion production and thus, avoiding unplanned well shut in. Furthermore, this function is especially useful when emulsion samples or historical data are not available during field development stage. Meanwhile, the recommended demulsifers from IOEMS are at 17% lower cost than the incumbent demulsifiers used at fields in Malayia, in addition to 90% manhour reduction from conventional trial and error demulsifier screening in lab.

Ultimately, the IOEMS has successfully enabled step-change in oilfield emulsion management via an efficient and reliable scientific based digital platform.
Increasing the Safety and Efficiency of Completions with the Utilization of Remote Manipulation Systems and Elimination of Hanging Sheaves
Authors: Alleman Neil
Published: March 2022

The process of running completions typically involves an increased complexity of systems and setups. The running of control lines and umbilicals have historically used hanging sheaves to route the lines from the spoolers to well center and require increased number of personnel in the red zone during operations. These complexities introduce many risks and potential incidents that operators aim to eliminate.

Typical procedures for running completions require man-riding operations to hang sheaves in the derrick. Once the control lines or umbilicals are routed through these sheaves, they become overhead loaded objects and subsequently increase the risk of incident to personnel working on the rig floor. Other operational steps include the manual manipulation of lines to clamp the lines/umbilical to the tubular. This traditional clamping procedure not only requires an increased number of personnel in the red zone, but it also introduces inefficiencies to the operation. Through planning and the use of specialized remote manipulation technologies, operators can remove the need for overhead control line/umbilical sheaves and the manual handling of lines in the red zone.

Although risks do not always result in incidents, organizations still strive to eliminate risks throughout their operations. By using remote manipulation technologies that eliminate control line/umbilical hanging sheaves, the operators benefit from the following:

– Eliminating working at height for sheave installation – Eliminating overhead loaded components and increasing safety of personnel working on the rig floor – Decreasing the number of personnel required in the red zone and reducing manual handling – Increasing the efficiency of the operation

By using systems like these, operators have been able to increase average running speeds, improving from 8.8 to 5.9 minutes per joint, as well as eliminate potentially fatal incidents that have occurred during the completions running process.
Management of Mercury Offshore for Onshore Production Facilities
Authors: Saaibon Mohamed Sopiee , Kayat Zainab , A Karim Fatimah
Published: March 2022

The objective of this paper is to provide an approach in mitigating the adverse effects of mercury found in production fields which include the evaluation on the requirement for mercury treatment facility and suitable technology and best location for the production fields and onshore LNG facilities. The evaluation included assessment of pipeline integrity and managing unexpected increase in mercury content to ensure Mercury Removal Unit (MRU) is capable to treat the gas within the design specification

The method includes mercury mapping and analysis of the results. Evaluation of technology and type at various streams in gas, condensate and water streams. There is no method to predict mercury production forecast and sizing cannot be based on one exploration well data only. Subsurface data might not be representative due to improper procedure, sampling, preservation and timing. Rigorous technology evaluation was evaluated for various mercury species covering its vulnerability to operations abnormalities such as entrainment of moisture, spikes of mercury content, changes to feed gas, hydrogen sulfide content, historical experience of mercury contamination and its impact to operations and performance of cryogenic systems and chemical injection for pipelines. Review of effectiveness of mercury removal technology for gas stream cover metal sulfide based adsorbent and metal oxide based with H2S in-situ sulfiding. In view that there is no proven technology for condensates stream, particulates mercury removal using filtration and hydrocyclones of the multiphase condensate /water and water streams were considered

Mercury has exceeded downstream design specification and pose threats to existing LNG facilities aluminum cryogenic heat exchanger. Speciation, particle size distribution and the use of a practical size test rig on site, adsorbent -condensate compatibility test are approaches to determine the capacity of the MRU. Based on the selected technology, concepts were derived for gas and condensate to ascertain the feasibility of mercury removal, particulate filtration, mercury impact to pipeline integrity and the basis for the onshore mercury removal facility. This yielded seven (7) different concepts or options addressing both MRU gas and condensate either at offshore platform or onshore facilities. The concept select ascertained the optimum requirement to install the mercury removal unit onshore upstream of an Acid Gas Removal Unit in the LNG facilities. A two-stage filtration to remove mercury particulates above 1 micron was selected for offshore facility.

Understanding the behaviour of mercury and the distribution tendencies into the various streams and factors that influence this distribution would provide insight on the integrity of production and pipeline system and management of mercury for operations.
Well Control Optimization of Offshore Horizontal Steam Flooding Wells Using Artificial Intelligence Algorithm
Authors: Han Xiaodong , Zhong Liguo , Wang Qiuxia , Zhang Wei , Zou Jian , Liu Hao , Wang Hongyu
Published: March 2022

Maximizing the future economic return of the asset is an important issue in petroleum engineering. For heavy oil reservoir developed with steam flooding, its production cost is much higher than that of conventional production methods. Commonly used parameters optimization method such as single factor analysis and orthogonal test cannot guarantee to obtain global optimal economic benefits. It is necessary and urgent to form a better optimization method to achieve higher profit.

A new framework is proposed and presented to optimize well control parameters of both steam injection wells and oil production wells by integrating the reservoir simulator into the optimization algorithms. A net present value (NPV) formula for evaluation of horizontal well steam flooding project is proposed and the optimization objective is to maximize the NPV of production over the life. The generally acknowledged Particle swarm optimization (PSO) is used for solution of the optimization problem. This method has been tested for a typical offshore horizontal well steam flooding project. Results indicate that PSO gives good solutions for this problem and the following conclusions can be obtained. The NPV of the optimized project is improved and larger than the NPV of its initial guess. The control frequency has great influence on the optimal NPV, and the optimal NPV increases with the increase of the control frequency. Steam injection and oil production rates need to be controlled and decreased at the latter stage for mitigating ineffective steam cycle between injection and production wells.

The new method has been used for well control optimization of the first offshore horizontal well steam flooding pilot and this method would which will provide powerful technical support for the high efficiency development of the heavy oil resource with steam flooding.
A Novel Apparent Permeability Model in Shale Gas Reservoirs
Authors: He Lang , Yang Bin , Liu Jing , Na Xinyue , Ge Yang
Published: March 2022

A novel apparent permeability model of shale gas is derived considering the stress dependence, the thickness of adsorbed layer, slip flow, Knudsen diffusion and surface diffusion. The thickness of the adsorbed layer is derived according to the porosity occupied by the adsorbed phase in the capillary model. Consequently, the impact of the adsorbed layer and its change with the pressure on apparent permeability can be clearly revealed in the novel model in ultramicropores, or micropores, or mesopores, or macropores. With the stress dependence and the thickness of adsorbed layer considered simultaneously, the effective hole radius is substantiated to be smaller than the original hole radius to a certain degree. On account of this, the ratio of apparent permeability to the intrinsic permeability computed by the novel model is a lot distinct from the existing models. As the pressure increases, the ratio in the novel model declines from above 1 to below 1, followed by a slight upward trend. However, the ratio in other models drops all the way and yet remains above 1 as the pressure rises. Finally, the impact factors of permeability, including stress dependence coefficient, hole radius, reservoir pressure, Langmuir volume and Langmuir pressure, are analyzed. The contribution of slip flow, Knudsen diffusion and surface diffusion to apparent permeability is also illustrated.
Mechanical Isolation of a Challenging Reservoir: First Installation of High Expansion Straddle Packer in Indonesia
Authors: Hidayat Reyhan , Kurniawati Pratika Siamsyah , Kurniawan Aries Taufiq , Setyaji Irwan , Pancawisna Gerardus Putra , Marindha Rantoe , Umar Khalid , Dahnil Gitani Tsalitsah , Rahman Risal , Jamal Muhammad Nadrul , Safitri Yufa , Azhar Raden-Muhamad Prayuda , Lodiman William , Syarif Hibroni
Published: March 2022

Well N-1 in Mahakam Sisi Nubi field, East Kalimantan, had a problem with water and condensate production up to 11,000 BLPD which instantly rendered the production facility overwhelmed despite the high 34 MMSCD gas rate. To solve this, reservoir production profiling using production logging tool was first carried out. Selection of existing zone isolation method was then compared, yet none satisfies the challenges in this well due to restriction and cost issues. A relatively new technology, High Expansion (HEX) Straddle Packer, was introduced as another alternative. A series of engineering design and followed by operation design was then carried out to solve the well problem safely.

A dummy tool run with 2.875" OD and 30ft of length passed through the restriction safely. Caliper logging observes reduction in tubing ID from 3.9" to 3.0". Temperature of the borehole reached 115 deg C at 3417 mBRT of this well. The two water producing zones were next to each other with a total top reservoir to bottom reservoir length of 11 m. With these values, a custom 2.7" straddle packer was built and tested to required temperature and passed. Production simulation with 0.7" ID, indicated the well could still flow over its critical flow regime. After installation, the well flows with 11 MMSCFD of gas with ~1800 BLPD liquid produced, a 83% reduction over previous liquid flowrate. Despite the well flows only 30% from initial gas rate, this well can now flow at an acceptable liquid rate.

The successful installation of the first HEX Straddle expands the portfolio of mechanical water shut off methods in Mahakam and in Indonesia as this was the first HEX Straddle installed in Indonesia. Further study and replications are needed, yet this method can be a viable alternative if other has failed for wells with similar problems.
A Literature Review on Site Suitability and Structural Hydrodynamic Viability for Artificial Reefs Purposes
Authors: Alsheikh Anas Khaled , Zawawi Noor Amila Wan , Liew Mohd Shahir , Shawn Lim Eu , Toloue Iraj , Danyaro Kamaluddeen Usman , Aszemi Nurshazlyn Mohd
Published: March 2022

In Malaysia, over 400 oil and gas platforms are in operation. In every life cycle of a platform, it undergoes decommissioning. The most used method is by relocating the asset to an onshore fabrication facility. The alternative to onshore decommissioning is by reefing structures in-situ or ex-situ basis. to achieve the environmental assurance of a successful decommissioning by reefing, two domains of parameters were overviewed. the study involved hydrodynamic simulation of platforms. The first domain is in relations to the site to determine its suitability against hosting marine life and thriving coral formulation (Site Suitability). the other domain is in relations to the structure's physical and hydrodynamic properties (structural viability). Site suitability is governed by water depth and current velocity. Structural viability is governed by two sub-domains, one is where dimensions and complexity of the structure are assessed using dimensionality analysis. And the other is its hydrodynamic properties (Vortex Shedding Frequency, Pressure, Wake Region indices).
Optimizing Tubular Running Services Through Digital Solutions – Doing More with Less!
Authors: Thibodeaux Robert L , Smith Logan E , Mahmood Azfar
Published: March 2022

Digital transformation is a term that continues to be popular with the oil and gas industry. The industry's historic opposition to the adoption of innovative technology seems to be fading as operators, contractors, and service providers alike continue to invest in innovative solutions around not only digital technologies, but also in process and system optimization techniques. However, while operators are more willing to adopt newer and automated technologies, the "proof of value" burden still falls on service companies. Perceived value to operators may vary slightly, but overall, the industry has focused on two core tenants of value: Increased safety and efficiencyPersonnel reduction

For widespread adoption of an enhanced digital solution, the technology must not only provide quantifiable value in at least one of the core tenants, but also must repeatably demonstrate the value in the field.

The case study presented demonstrates the value added by introducing a new proprietary Programmable Logic Controller (PLC) based solution into the tubular running process. This system allows for tong operation, elevator and slip function, and single joint elevator (SJE) operation to be performed by a single person, rather than three or four personnel crew, as traditionally employed during tubular running operations. All functions are intelligently executed from a triple certified hazardous zone rated wireless tablet by a single operator's command while located inside the driller's cabin.

Through the deployment of a new consolidated and intelligent control system, the rig was able to reduce the number of personnel typically required for casing run and rack back operations down to two operators per tower, which equates to as much as a 66% reduction in personnel needed for tubular running operations. Additionally, the system allowed the operator to control the equipment from inside the driller's cabin, which improved communications and reduced red zone exposure by 30% while increasing run time efficiency by as much as 11% on some connection strings.
Oilfield Microbiology: Case Study of Molecular Techniques for Determining the Risk of Microbiologically Influenced Corrosion MIC
Authors: Bennet Douglas Grant
Published: March 2022

The objective of this paper is to explain the beneficial information obtained during a microbiological study of an oilfield survey, where molecular microbiology techniques where utilised. The inclusion of these techniques highlighted information that would have otherwise been missed and/or misinterpreted.

The molecular microbiology techniques deployed during this survey included Quantitative Polymerase Chain Reaction (qPCR) and Next Generation Sequencing (NGS).

The aim of PCR technology is to specifically increase a target (gene) from an undetectable amount of starting material. The first step is extraction of DNA from the sample, which will subsequently be subjected to the qPCR technology. During qPCR gene copies are made during thermocycling and a fluorescent marker accumulates, which can be used to quantify the target gene.

Similar to the PCR technology, DNA is extracted from the sample and the DNA is amplified. In NGS, this is then sorted into a library of small DNA segments before they are amplified. During the sequencing step each DNA fragment amplified is sequentially identified from light signals emitted by comparing with a DNA library.

The results obtained indicated crucial additional information that was not detected by traditional methods. In addition to much higher, truer quantification of known populations of Total Prokaryotes and Sulphate Reducing Prokaryotes, identification of other groups of DNA was possible through the NGS technique analysis. The results provided valuable information, which has subsequently been used to apply successful, targeted mitigation strategies to reduce the risk of MIC to assets.
Use of Oxygen Scavenger in Well Safety Valve Balancing Operations
Authors: Lehmann Marc , Lepkova Katerina , Pojtanabuntoeng Thunyaluk , Ghodkay Varun , Greenwood Annamaria , Hirano Susumu , Sunaba Toshiyuki
Published: March 2022

Monoethylene glycol (MEG) is often used to reduce the differential pressure across well valves so that they can be opened without damage. This MEG ultimately commingles with production fluids and if not deoxygenated contributes to the overall content of dissolved oxygen that may be seen by a receiving production facility. Normally, the dissolved oxygen levels would be removed to insignificant levels during fluid transport. Since the corrosion reactions sequester the oxygen as the fluids are exposed to less noble materials of construction, such as carbon steel. However, in facilities that utilise corrosion resistant alloys (CRA) the residual dissolved oxygen level can be so significant that it warrants reduction using oxygen scavengers. This paper reports on corrosion studies that illustrate the consequence of dissolved oxygen levels being carried through to a MEG reclamation unit constructed of CRA, and laboratory and field validation studies on the use of a bisulfite-based scavenger for removal of oxygen in 90wt% MEG used for equalising pressure of Subsurface Safety Valves.
Cyclic Behaviour of a Malaysian Deepwater Clay
Authors: Colreavy Cathal , Boylan Noel , Andersen Knut H , Huang Noorizal Nasri , Girsang Christian Hariady
Published: March 2022

Offshore structures are subjected to cyclic loading from a range of sources and an appreciation for how the underlying soil responds to that loading is essential for design. The behaviour of soil under cyclic loading differs to that from monotonic loading and advanced laboratory testing is required to assess this behaviour. This paper describes the behaviour of a deepwater soft clay under cyclic loading. The site is located offshore Sabah, Malaysia in water depths up to 1,200 m. As part of the geotechnical investigation for the site, a suite of cyclic simple shear tests was carried out on samples retrieved from boreholes on the site. Results from this suite of tests were used to establish a set of cyclic contour diagrams for the site. These contour diagrams will be used in the design of foundations for offshore structures at the site. This is the first comprehensive study of the cyclic behaviour of deepwater Malaysian clay. As such, they provide a useful starting point for the development of contour diagrams in similar soils.
Improving Aging Field Value Through Production Data Revitalization
Authors: Jamaludin Izzuddin , Tan Zhao Zheng , Surin Nicholas Aloysius , Hew Zhong Ying
Published: March 2022

Field-D consists of multi-stacked oil reservoirs with commingle production and dual strings. Well integrity issues are main challenges causing crossflow between zones and unintentional production/injection. With massive effort of rebuilding static model and rework on history matching (HM), many inconsistencies of production data allocation were discovered, such as oil recovery factor (RF) >60%. This paper discusses the exercise of cleaning up production data as per latest subsurface understanding and memory production logging tool (MPLT) campaigns.

Reinterpretation of stratigraphic correlation, depositional environment, and petrophysical parameters are among major workflows during the static model rebuilding process. As current reservoir allocations are based on legacy permeability-thickness (KH) ratio, the requirement to revise allocation split based on latest understanding is considered compulsory. This is further justified by dynamic modeling HM exercise where inconsistencies are observed between legacy data and model response, resulting in poor HM quality and unrealistic RF, suggesting different production/injection distribution than in current database. Additionally, MPLT campaign is executed every year to obtain latest split percentage. A pilot exercise is embarked on to redefine contribution for each zone in every well in fault block VIII and rerun allocation starting day 1.

Successful production data allocation rerun is expected to demonstrate representative RF for individual reservoir. Higher RF are expected for zones with secondary drive mechanism i.e., water and gas injection, as opposed to natural depletion reservoirs (NDR). This exercise also will enable accurate reporting during the Annual Reporting of Petroleum Resources (ARPR) to the host government. Additionally, more accurate forecast using decline curve analysis (DCA) can be realized, and robust analysis can be performed to improve respective reservoir RF. Better well management also is anticipated as zonal isolation such as water or gas shut off or adding perforation jobs can be properly planned and executed. Looking from injection well point of view, proper distribution will be possible so that only targeted zones will receive the pressure support. A full field implementation is currently ongoing for the rest of fault block in Field-D.
Disruptive Dumpflooding Completion, Case Study Ecuador
Authors: Pleshkov Dmitry , Corella Moya Carlos Andres , Corella Moya Byron Ricardo , Ortiz Angel Vicente Silva , Paredes Luis , Huaca Augusto , Chicaiza Freddy , Marin Gustavo Ariel , Garcia Jose Norberto , Tapia Raul Armando Valencia , Rajain Anur Kumar
Published: March 2022

Most of the fields in Ecuador are considered "mature." Water injection is a well-known solution for mature fields. Water injection projects require a source of clean water. Traditionally, minimum specifications are achieved by surface treatment facilities. However, in the Ecuadorian Oriente Basin, the Hollin reservoir is an active aquifer with water meeting the requirements for use in waterflooding. But in other cases, water from production wells and from traditional surface facilities requires high investment costs because of associated facilities, chemical treatments, water production lines, and other requirements. A novel completion design has been developed. This proposed completion is called "modified dumpflooding" and represents a cost-effective solution for Ecuadorian mature fields. Dumpflooding is a modified version of dual concentric completion using most of its configuration pieces. It also takes advantage of extensive local experience in dual concentric completion design. Modified dumpflooding completion enables companies to use just one well for water production, injecting it into the depleted reservoir as a closed loop. Additionally, it helps to save costs in surface facilities by reducing human exposure to high pressure lines over large distances and eliminating operational expenditures for chemicals and equipment maintenance. Nodal analysis is foundational to helping companies understand how current design of waterflooding projects is behaving. It also provides a basis for mechanical configuration optimization to reduce bottlenecking points and improve completion performance.