bluuebunny/crossref_metadata_2025_split huggingface dataset:
Long Term Development Implications of Parent-Child Interactions in Unconventional Reservoirs
Authors: Srinivasan Karthik , Faulk Andrew Bryce , Sanders Karen Elizabeth , Guice Kyle Brandon , Ramirez Melissa Y , Mohan Lavanya , Rajput Nandini , Weisman Daniel , Malpani Rajgopal 
Published: October 2023

Abstract
This paper examines the impact of parent depletion on well performance of child wells in a stacked pay unconventional basin with horizontal wells landed in multiple benches. Both intra-bench and inter-bench parent-child were considered, and examples described. This paper also addresses future development implications that result from best-bench-first development in stacked unconventional plays as a function of degradation in child well EURs. This work focuses on both horizontal/vertical interference where presence of pre-existing fracs and depletion in parent wells impact fracture height growth/length and resulting productive frac size in child wells.
Two case studies were selected to demonstrate intra-bench and inter-bench parent-child degradations. In the first case study focused on intra-bench parent/child, two adjacent development sections were evaluated, each having been developed as phased developments (multiple landing targets) and with a 9-month lag in first production between the sections. In the second case study focused on inter-bench parent/child, two nearby sections were considered in which different phased development strategies were employed across three distinct landing targets. In both case studies, significant child well degradation was observed in both bottom hole pressures and well production data; observations of impacts to parent wells were also noted. These findings are further supported by modeling efforts.
Combined, these case studies indicate that both inter-bench and intra-bench parent-child are significant concerns in stacked unconventional plays, such as those found in the Permian Basin. Our attempts to fully negate the impact of parent-child through later development choices, or to develop child wells without waste, have proven unsuccessful. Complete mitigation of parent-child impacts requires both co-development of potentially connected landing targets (inter-bench) and mow-down development of adjacent development sections (intra-bench).
The Best-In-Class Implementation of Dual ESP Technology in an Abu Dhabi Mature Offshore Oil Field to Successfully Extend Well Life with Significant Contribution to Sustainability
Authors: Abdelkerim A. I , Ballah S. , Al Ameri M. , Obeid A. , Arawi A. , Sanghavi D. 
Published: October 2023

Abstract
A mature offshore Abu Dhabi oil field produces from a heterogeneous carbonate limestone reservoir with an important column of bottom aquifer. The reservoir heterogeneity is characterized by presence of karst filled with fine materials at top section, conductive faults, fractures, and significant variation of rock properties. As a result, the natural wells exhibit short life due to rapid water cut increase with water encroaching into wellbore from bottom aquifer through conductive faults. To mitigate this issue, the field development strategy has been revised to install ESP in all producers to sustain oil production by extending well life while maximizing operating efficiency and overall field ultimate oil recovery. Starting from 2001, conventional single ESP was successfully piloted in 4 wells, which provided run life up to 3 years on average including some premature failures. As the field has a small number of wells with limited allocated rig resources, the ESP well remains idle between 3 to 6 months after ESP failure while waiting for replacement by rig. This resulted in significant oil production volume loss and higher unit lifting cost. Hence, the field development decided to pilot dual ESP in 2015 with 2 ESPs in series with one running and another on standby in hole as backup. The objective is to reduce downtime and deferred or lost production volume while mobilizing rig and equipment for workover. Consequently, after successful piloting, a total of 6 dual ESPs were installed from 2015 to 2023 helping to extend well life by up to 2 folds, contributing to sustain production and reduce lifting cost from two to one digit. As a result, the field was able to deliver production mandate ahead of planned date and provided incentive to plan for further production increases with higher operating efficiency and lower operating cost.
This paper describes the outstanding process of dual ESP design, installation, operations, and the performance, illustrating the best-in-class artificial lift performance results.
An Autonomous Approach to Mitigate Risks Associated with Well Intervention in ESP Completed Wells
Authors: Balkhair O. M. , Afif O. T. , Aljindan A. A. , Raad A. F. 
Published: October 2023

Abstract
Well intervention is an essential overall part of maintaining the integrity of wells. Moreover, intervention methods can differ based on each respective well completion. For well intervention purposes, a Y shaped tool (Y-Tool) is installed which usually accommodates an ESP's completion. The proposed paper suggests a process that utilizes an Automatic Y-tool completion which eases well intervention operations. Using a blanking plug is the norm when it comes to ESP completions equipped with Y-tool where it provides a good seal and prevent the fluid from flowing into the bypass profile. Moreover, setting or removing the blanking plug can be quite challenging if any obstruction has accumulated in the bypass profile. An automatic y-tool completion can be an effective solution where it provides a reliable ball/seat seal and eliminates the risk associated with any attempts involving the installment or removal of blanking plugs. The y-check tool features a moving ball that is triggered by the flow and pressure produced by the ESP, which in turn moves the ball seal into its respective seat and seals the desired section of the completion. After the successful installation of the automatic y-tool completion, the ESP performance was observed to ensure that there is no leak in the ball/seat sealing mechanism and that it can be utilized in the upcoming well intervention operations. This paper will illustrate the challenges associated with the blanking plug and benefits introduced in the automatic y-tool. This will be reflected on the ESP performance that will ensure the functionality of the automatic y-tool, and the highly effective intervention operation that can be conducted with a system such as the one mentioned in the paper. The paper discusses the detailed process in effectively utilizing the automatic y-tool in well intervention operations, which in turn provides a more efficient alternative for well interventions in completions with an ESP installed.
Novel Plug and Perf Technique in Monobore Completion of Jurassic Gas Well in Kuwait
Authors: Al-Matar Mohammad , Theyab Abdullah , Al-Mubarak Hamad , Al-Shammari Faisal , Al-Jaber Mohammad 
Published: October 2023

Abstract
Various wells completed nowadays can be classified as short-life or harvest wells. Some of these would not be economically feasible using high-end completion components and methods. Monobore wells can be a solution to this dilemma. Meanwhile the strategy of Kuwait is in growth direction and demand increasing of oil and natural gas production. Consequently, the company will eliminate the requirement of the workover rigs, while enabling the selective stimulation.
A 4 ½" monobore completion well was first implemented in Kuwait in Jurassic fields. In the direction of maximizing the production while enabling the vast majority of rigless intervention operations including the plug and perf technique, full drift cleanouts and high rate stimulation. Plug and perf technique provides the ability of carrying out the selective stimulation and testing for each individual zone independently. Treatment can be tailored for each zone whether it is a matrix stimulation or hydraulic fracturing which maximizes the production and reduces the formation damage.
This paper will begin by reviewing the increasing of oil and gas production by using plug and perf technique in monobore completion wells. In addition, using plug and perf technique in Jurassic oil and gas wells, and employing the monobore completions, the number of rig based workovers diminished by a huge margin due to the ability of utilizing the rigless workover, such as: coiled tubing, wireline, slickline. These efforts reduced the cost by a massive amount as well as getting the production back online in very short time. Kuwait Oil Company can isolate each zone if they produce water easily and directly without need of using any workover.
This paper shares the successes, challenges and lessons learned from the monobore wells in Kuwait that were produced by the Plug and Perf technique, and the consequent interventions to achieve the maximum production.
Dynamic Underbalance Perforating for Production Enhancement and Frac Optimization in Tight Gas Wells: Case Study from Sultanate of Oman
Authors: Suleimani Ahmed Al , Al Hinai Adnan Saif , Nunez Alvaro , Al Rasbi Said 
Published: October 2023

Abstract
The objective of the paper is to demonstrate the effectiveness of the dynamic underbalance (DUB) perforation technique, especially in enhancing the performance of deep tight gas wells in the Sultanate of Oman. The technique aims to provide cleaner perforation tunnels, eliminate perforation damage, and improve flow/injection by creating a sharp, localized pressure drop across the perforation interval immediately after the perforation tunnels are formed.
The paper begins with an overview of the operation and the nature of the deep tight gas wells in the field, with particular emphasis on the tight reservoir with low permeability. It underlines the importance of combining deep penetration jet charges with dynamic underbalance (DUB) to achieve deep and clean perforation tunnels which helps in reducing the perforation skin and improving connectivity with the reservoir, contributing significantly to optimizing the hydraulic fracturing job that results in lower breakdown pressure and more successful frac placement.
This paper presents field examples where the dynamic underbalance (DUB) technique was applied in multiple tight gas wells. Details include the use of a 2 7/8" gun configuration in 4.5" completion size with a fast pressure gauge run alongside the perforation gun to measure the extent of dynamic underbalance created by the gun system. These actual measurements were then compared with estimated dynamic underbalance values derived from pre-job simulations using proprietary software. The results largely mirrored the predictions, indicating the effectiveness of the modeling process.
In most cases, we observed a reduction in the treating pressure required for fracturing. Despite high formation stresses in some wells which limited the impact of DUB, a great improvement in initial production rates was observed, compared to projected rates.
The results demonstrate the effectiveness of the DP perforation guns with DUB perforating technique in enhancing connectivity with the reservoir, leading to achieve higher production flow rates. This effective performance eliminated the necessity for fracking in the designated zone. Also, the effectiveness extends to the pre-frac perforation application in achieving breakdown and fracture placement in the ultra-strong formations of field B, where rock strength exceeds 30 KPSI. In such challenging formations, conventional gun systems often struggle to initiate breakdown pressure in these formations and abrasive jetting with coiled tubing has typically been utilized to initiate fracturing in this environment however, it is costly, big footprint and much less efficient. The adoption of DP perforation with DUB technique has substantially enhanced both efficiency and cost savings.
Improving Reservoir Efficiency by Drilling Super Slim Multilateral Wellbores
Authors: Zakirov Z. , Galiev R. , Miftahov R. , Galimova N. , Karimov T. 
Published: October 2023

Abstract
Oil production in brownfields has a wide variety of challenges. The brownfield operators’ main goal is to maintain desired production rates, keeping the OPEX and water cut ratio low. The small-diameter wells today are a common asset of E&P companies. Once the small-diameter wells are deteriorating in hydrocarbon production rates, the question of the financial viability of these assets’ rejuvenation is associated with high uncertainties: lack of proven simulation methodologies, formation water intrusion risks, and other challenges. This paper describes the results of super-slim laterals drilling from a small diameter wellbore. The required downhole tools were engineered to tailor small-size lateral wellbore drilling and completion-associated challenges. The newly developed technology has been also implemented to better reach hydrocarbon reserves.
Session: 47 | Health and Safety: Human Factors and Process Safety
Authors: Aslam M. , Venkatesan K. , Ahmed S. , Ketbi A. Al , Ahmed M. S. , Alshehhi K. , Haider F. , Al Mazrouei M. K. 
Published: October 2023

Summary
More than 30% incidents in Oil & Gas sector involving storage tanks have been caused by human error, including poor operations and maintenance practices. Several LOPC and major accidents in Oil and gas industry have been attributed to the improper flushing and purging of hydrocarbon systems prior to handover the facility/system for maintenance or project related tie in activities. Tight shutdown plans especially in the brown field projects is major forcing factor for operation staff to cut the corners and take short cuts in order to achieve the project milestone and production mandate on time. Complexity of the piping network is adding difficulty to the problem which makes the process of isolation/flushing/purging quite time taking. Several incidents across various industries were studied as part of the assessment methodology to identify the root causes to reach the proper solution. Inadequate engineering designs adding dead legs to the system contributing to the difficulty in freeing system from hydrocarbons. This solution can be applied to any oil and gas facility for minimizing the shutdown duration and ensuring safe execution of critical activities in brown field projects execution. During design optimization and value engineering reviews of the new facilities, long terms operational impacts are overlooked, which could result in potential dead legs and unavailability of adequate isolation points.
Cost Model Optimization of Integrated Drilling Services Contracts in Delivering Economical and Fit for Purpose Development Wells for Petronas Operated Field in Middle East
Authors: Aldarkazly H. , Sze W. Han , Alam R. Rj Zainal , Ali A. Md , Yusof W. Y. Wan , Ramli A. , Affendy M. K. , Al-Shaheen H. , Mutlag W. , Marzoq A. , Alqasim M. , Jamal A. , Ismail A. L. , Nazarudin M. Bin , Johar J. H. , Hamat W. Che 
Published: October 2023

Abstract
Cost optimization is an ever-enduring subject in drilling industry. PETRONAS, as a prudent operator of an oil field in Middle East, constantly pursues for means in optimizing drilling cost which makes up between 50-70% of a typical development project CAPEX, ensuring the projects stays economical to PETRONAS while still delivering its production commitment and values to its stakeholders. In ensuring PETRONAS and its partners investments remain protected, all drilling operations related risk compounded with regional specific risks must be accounted for and addressed in its contracting strategy. In such situations, typically an operator would opt for a turn-key or Integrated Drilling Services (IDS) approach contract in ensuring its cost are capped. However, placing considerable risks to IDS contractor will subsequently driving the well cost up. Tailoring a fit for purpose cost model of IDS contracts is vital in striking the balance between profitability of contractor and cost savings for operators. In this paper, an analysis for different cost models for IDS contracts that have been successfully implemented in one of the oil fields in Middle East by PETRONAS will be elaborated.
Three types of cost models have been incorporated by PETRONAS in one of the oil fields in Middle East for several IDS contracts during their tendering process. These cost models are lumpsum cost per well, lumpsum cost per meter and lumpsum cost per hole section. The wells were drilled to the same reservoir with identical well design and drilling operation sequences using rigs with same specifications in order to achieve fair comparison.
The awarded contracts with the three different cost models resulted in a range of well cost. Several advantages and disadvantages were observed during contract execution of each IDS contract implementing the different cost models. The lowest well cost in terms of IDS unit price was achieved by IDS contract utilizing lumpsum cost per hole section model. A cost reduction of up to 50 % was achieved compared to other IDS cost models. All the wells were drilled and delivered safely meeting the well objectives.
In some areas of Middle East, drilling operations are challenging due to constant security concerns which led to multiple operation suspensions, in addition to typical carbonate drilling challenges which resulted in higher drilling cost as compared to regional average. This paper would help the other oil field operators to utilize the IDS contracts with a proven and reliable cost model that ensures drilling the wells with lowest cost. PETRONAS has drilled more than 125 wells in one of the oil fields in Middle East utilizing various models of IDS contracts.
First Multilateral L4 Well with Six Open Hole Laterals in Middle East: Drilled and Stimulated All Laterals Under Challenging Reservoir Condition and Enhanced Production
Authors: Al-Otaibi Fahad Fares , Al-Awadhi Shareef , Ali Unneen Rijun , Dutta Abhijit 
Published: October 2023

Abstract
High level multilateral technology can access multiple reservoirs with lateral junction integrity, increase drain hole lengths that can result in enhanced production from a single location and significantly lower construction cost. It can also access conventionally unreachable reservoir thereby recover bypasses oils and enhance production objectives. This paper focusses on successful deployment of TAML 4 systems in Kuwait field providing independent accessibility of both laterals during life of well for cleaning, stimulation, zonal isolation, selective production, data acquisition, etc. It also details challenges faces while installing high level multilateral system, drilling six horizontals including three through multilateral junction and accessing both main bore and lateral. Paper details on completion designs, drilling challenges in complex reservoir structure and also discusses challenges of individually accessing all six open hole laterals successfully with advanced Coil Tubing System that allowed acid stimulation in each carbonate lateral and enhanced production.
The success of Multilateral Level 4 having six open hole horizontals comprising three in each of the two laterals that could be individually accessed through TAML 4 system and expected to produce significant amount of hydrocarbon trapped in formation with high degree of reservoir rock and fluid heterogeneity. The paper focuses on the challenges, solutions, and successful case study of the first Level 4 Multilateral having six open hole horizontals drilling in the Middle East. The paper also provides detailed workflow methodology for improving reliability of multilateral installations to maximize efficiencies. Successful acid stimulation using advanced Coil Tubing System that enabled selective entry into each of the laterals also enhanced production.
The successful application of TAML L4 would open new avenues of well construction that would enhance production at reduced cost and reduce surface location footprint in Kuwait fields.
Case Study on Catastrophic Failure of the Cooling Water Pump DE Bearing
Authors: Whittaker Simon , Sidhu Sanjit , Subramanian Moorthy 
Published: October 2023

Abstract
Case study on Catastrophic Failure of the Cooling Water Pump DE Bearing due to High vibration and Flow turbulence.
The Cooling water pumps are the core unit in the Gas separation plant for cooling the Condenser during gas separation process and these pumps are required in operation 24/7. This case study represents the Catastrophic Failure of the Cooling Water Pump DE Bearing assembly due to High vibration and Flow turbulence within 90 Days from the commissioning.
The function of a cooling system is to remove heat from processes or equipment. Heat removed from one medium is transferred to another medium, or process fluid. Most often, the cooling medium is water and the same get cool into ambient temperature when passes through the Cooling tower. In Oxygen gas production cooling water is circulated into the Surface condenser to remove the head during gas separation. High-capacity cooling water pump (6000 m3/hr.) plays an important role for continuous circulation of the cooling water in the closed loop.
During operation, a sudden increase in Pump B DE bearing temperature and immediately the pump tripped due to high current. During site inspection we found the DE Bearing housing was cracked and Pump rotor was shifted towards the Motor.
We have noticed the peaks at 1x, 7x & 14x in the FFT Spectrum along with Raising Floor noise which give the sign for the Flow turbulence/cavitation and VP Frequency.
Additionally, inspection on the Pump internals and other parameters was checked.DE bearing was completely damaged condition.DE Mechanical seal was also damaged condition.Found there was VPF and turbulence in the vibration spectrum.The Suction and Discharge piping was inspected, and suction isolation (Butterfly valve) position was shifted from Vertical to Horizontal for operator convenience.
Performed Butterfly Valve flow pattern using the software tool and found the most recommended pattern is vertical. Flow turbulence could occur if the Butterfly valve is in Horizontal position as this is Double suction pump.
The suction piping with necessary Valves and fittings needs to be designed & installed as per Pump OEM recommendation as it is important for the Pump to operate without any interruption. The Valve position is also very important and if any changes at site and the same required approval from the OEM.
Optimization of the Well Diagnostics Investigation
Authors: Yugay A. , Zhukin A. , Vorozhikhin S. , Girgis F. , Alkarbi M. A. 
Published: October 2023

Abstract
Well Integrity discipline is all about barriers. Double barrier envelope policy is a well integrity requirement well-known worldwide. This can be found in international standards: API RP90 (1 & 2), Norsok D10, ISO 16530 (1 & 2). This policy applies to wells with positive pressure at surface capable to flow naturally. Primary barrier envelope consists of well equipment which is in direct contact with produced or injected media. Secondary barrier envelope will be exposed to well media in case of primary barrier element failure. This paper focuses on such kind of wells that have a positive pressure at surface and fall under double barrier policy.
Any failure in primary barrier envelope (means - completion) is easily repairable during workover by simply re-completing the well with new completion. This can be done almost unlimited number of times, as long as there is a place to set the packer. Failure in secondary barrier envelope (means - casing) can be done as well, but not that easy and limited amount of time. In some cases, especially for onshore wells it might be economically more reasonable to drill the new well rather than to deal with complicated workover. Depending on the Company policy, casing integrity can be restored in sections using casing patches or the entire length can renewed by running and cementing casings of smaller diameter. Obviously, in both cases it impacts the size of the completion and cannot be done multiple times.