First Implementation of High-Rate Pinpoint Technology in an Extremely Challenging Multilateral Well: Successful Lessons Learned From Tight Carbonate - Minagish Field, West Kuwait

2019 ◽  
Author(s):  
Mohamed Mofti ◽  
Leopoldo Sierra ◽  
Alaeldin Saad Frag Alboueshi ◽  
Milan Patra ◽  
Sulaiman Ali ◽  
...  
Keyword(s):  
Lessons Learned ◽  
High Rate ◽  
Tight Carbonate

First Implementation of High-Rate Pinpoint Technology in an Extremely Challenging Multilateral Well: Successful Lessons Learned from Tight Carbonate - Minagish Field, West Kuwait (Russian)

2019 ◽  
Author(s):  
Mohamed Mofti ◽  
Leopoldo Sierra ◽  
Alaeldin Saad Frag Alboueshi ◽  
Milan Patra ◽  
Sulaiman Ali ◽  
...  
Keyword(s):  
Lessons Learned ◽  
High Rate ◽  
Tight Carbonate

A Cost-Effective Stimulation Workflow Unlocks New Perspectives for Matrix Acidizing in Openhole Horizontal Tight Carbonate – A Case Study from West Kuwait

2021 ◽  
Author(s):  
Salem Al-Sabea ◽  
Milan Patra ◽  
Abdullah Abu-Eida ◽  
Nasser Al-Azmi ◽  
Mohammad AlEidi ◽  
...  
Keyword(s):  
High Pressure ◽  
Cost Effective ◽  
Lessons Learned ◽  
Carbonate Reservoir ◽  
High Rate ◽  
Distributed Temperature Sensing ◽  
High Permeability ◽  
Study Results ◽  
Tight Carbonate ◽  
The Impact

Abstract The Mishrif formation in west Kuwait is a tight carbonate reservoir having low oil mobility. It is fractured and heterogeneous with wide variation in porosity ranging from 10 to 25%, matrix permeability of about 0.1 to 10 md, and 20°API oil. Production tests and geomechanical study results have revealed that productivity is mostly from the high-permeability matrix and critically stressed fracture networks. Recently, the Mishrif development has been dominated by horizontal wells to maximize reservoir contact and enhance productivity. However, a challenge in such openhole completion is the stimulation strategy requiring effective diversion technology due to the uneven acid distribution along the lateral section. To address those challenges, a novel engineered workflow has been implemented relying on distributed temperature sensing (DTS) to assess the fluid coverage across the openhole section. Results enable identifying high- and low-intake zones, segmenting the uncased section into intervals requiring different levels of stimulation, and making informed decisions regarding diversion requirements. The intervention was conducted in two stages. Coiled tubing (CT) was the selected fluid conveyance method on the first stage given its capacity for more controlled fluid placement, and high-rate bullheading stimulation was selected for the second stage. During the treatment, multiple challenges were faced, mainly driven by a high-permeability streak identified by the DTS near the heel of the lateral. The CT stimulation procedures were modified on the spot, and measures were taken to minimize the impact on the thief zone, which included a combination of diversion techniques, such as high-pressure jetting, dual injection, and pumping of a near-wellbore nonreactive diverter, which is composed of a customized blend of multimodal particles and degradable fibers to minimize fluid leakoff into the high-intake zone. Likewise, real-time downhole telemetry was crucial throughout the CT stimulation because it allowed the highest injection rate possible below the preset pressure limits, continuous monitoring of downhole dynamics along the intervention, and optimal actuation of the high-pressure jetting tool. Upon completion of the CT stimulation, a second DTS log was carried out to evaluate the fluid coverage and effectiveness of the diversion strategy, enabling further adjustment of the bullhead stimulation program. This stimulation workflow implemented in west Kuwait represents a cost-effective alternative to stimulate openhole tight carbonates. This study brings new perspectives for treating complex reservoirs in the region, and shares lessons learned for future interventions.

Subsea Multiwell High-Flow-Rate Riserless Acid Stimulation Campaign With Two- Vessel Approach: A Comparative Case Study

2021 ◽  
Author(s):  
Irma Kusumawati ◽  
Birger Heigre ◽  
Hunter Whitfield ◽  
Samuel Bremner ◽  
Andrea Sbordone ◽  
...  
Keyword(s):  
High Pressure ◽  
Control System ◽  
Pressure Support ◽  
Operational Efficiency ◽  
Lessons Learned ◽  
High Rate ◽  
Comparative Case Study ◽  
Operating Efficiency ◽  
Injection Wells ◽  
Well Control

Abstract This paper describes the utilization of a riserless light well intervention (RLWI) vessel with well control system and flexible downlines to execute a re-stimulation campaign on subsea injection wells located in the Norwegian Continental shelf in the summer of 2019 and 2020. A riserless light well intervention (RLWI) vessel with well control system and flexible downlines was used in combination with a stimulation vessel. The objective of each campaign was to increase injectivity in the wells with high-rate acid treatments. The lessons learned from the 2019 campaign were applied to the 2020 campaign, resulting in reduced health and safety exposure, and improved operational efficiency. Analysis of the treatments and their impact on injection and field pressure support was conducted to assess the effects of these improvements and provide insights for how the treatments can be applied to vessel stimulation in general. In each campaign, the RLWI vessel was connected to the subsea asset, and a dedicated stimulation vessel provided stimulation fluids via a high-pressure flexible hose connected between the two vessels. Both campaigns saw high treatment pump rates of up to 60 bbl/min with low-pH crosslinked gel fluids, 28% hydrochloric acid, and diverters in the form of ball sealers and rock salt. Hose deployment methodologies between the two vessels differed in the two campaigns. The 2019 campaign employed a conventional transfer utilizing the marine crane on the RLWI vessel to lift and lower the hose into a preexisting hanger. Learnings from this operation led to the development and use of a winch pull-in method in which the hose connection was accomplished with a hot stab connector on the RLWI vessel, eliminating human intervention and the use of the crane. The 2019 and 2020 campaigns successfully stimulated five and six subsea injection wells, respectively, and realized post-stimulation improvement in injection rates of 135%. One year of field monitoring from the first campaign shows pressure support benefits with improvements in production throughout the connecting area of the field. The winch pull-in method of hose deployment between the vessels achieved time improvements of 8 hours per stimulation treatment. In addition, the added flexibility of not needing to be within crane reach gave the operation extended working weather limits. The overall result was a significant improvement in operating efficiency between the 2019 and 2020 campaigns. The operations showed how high-rate stimulation can be achieved on subsea assets with the use of an RLWI and stimulation vessels. Detailed analysis of the operational efficiency of each campaign was performed, and the improvements from one campaign to the next documented. The winch pull-in method is a new way of high-pressure hose transfer that can be applied to future stimulation vessel operations to improve operational safety and efficiency.

A Single-Center Experience with Minimally Invasive Transgastric ERCP in Patients with Previous Gastric Bypass: Lessons Learned and Technical Considerations

2020 ◽  
Vol 86 (4) ◽  
pp. 300-307
Author(s):  
Maria Baimas-George ◽  
Michael J. Passeri ◽  
William B. Lyman ◽  
Andrew Dries ◽  
Tarun Narang ◽  
...  
Keyword(s):  
Minimally Invasive ◽  
Biliary Obstruction ◽  
Operative Time ◽  
Lessons Learned ◽  
High Rate ◽  
Single Center Experience ◽  
Estimated Blood Loss ◽  
Chart Abstraction ◽  
Feasible Alternative ◽  
Median Operative Time

As bariatric surgery increases, there is a growing population of patients with biliary obstruction and anatomy which precludes transoral access through endoscopic retrograde cholangiopancreatography (ERCP). Minimally invasive transgastric ERCP (TG-ERCP) offers a feasible alternative for the treatment. A retrospective review was performed of all patients who underwent laparoscopic or robotic-assisted TG-ERCP between 2010 and 2017. Chart abstraction collected demographics, procedural details, success rate, and postoperative outcomes. Forty patients were identified, of which 38 cases were performed laparoscopically and two robotically. Median operative time was 163 minutes, with an estimated blood loss of 50 cc. TG-ERCP was performed successfully in 36 cases (90%); sphincterotomy was completed in 35 patients (97%). Sixty per cent already had a cholecystectomy; in the remaining patients, it was performed concurrently. Major complications included stomach perforation (n = 1), pancreatitis (n = 3), and anemia requiring transfusion (n = 2). In patients with biliary obstruction and anatomy not suitable for ERCP, TG-ERCP can be performed in a minimally invasive fashion, with a high rate of technical success and low morbidity. We describe a stepwise, reproducible technique because it is an essential tool for the shared armamentarium of endoscopists and surgeons.

Well Testing to Full Potential: Lessons Learned and Best Practices for High Rate Wells

2019 ◽  
Author(s):  
Florian Hollaender ◽  
Yakov Shumakov ◽  
Ozgur Karacali ◽  
Bertrand Theuveny
Keyword(s):  
Best Practices ◽  
Lessons Learned ◽  
High Rate ◽  
Full Potential ◽  
Well Testing

World's First Extension Pack with 7-in. Enhanced Single-Trip Multizone System: Success Case and Learning Points on the Installation and Treatment Design

2021 ◽  
Author(s):  
Sunanda Magna Bela ◽  
Abdil Adzeem B Ahmad Mahdzan ◽  
Noor Hidayah A Rashid ◽  
Zairi A Kadir ◽  
Azfar Israa Abu Bakar ◽  
...  
Keyword(s):  
Reservoir Characterization ◽  
Development Planning ◽  
Development Project ◽  
Lessons Learned ◽  
High Rate ◽  
Individual Treatment ◽  
Flow Area ◽  
Field Development ◽  
Well Completion ◽  
Gravel Pack

Abstract Gravel packing in a multilayer reservoir during an infill development project requires treating each zone individually, one after the other, based on reservoir characterization. This paper discusses the installation of an enhanced 7-in. multizone system to achieve both technical and operational efficiency, and the lessons learned that enabled placement of an optimized high-rate water pack (HRWP) in the two lower zones and an extension pack in the uppermost zone. This new approach helps make multizone cased-hole gravel-pack (CHGP) completions a more technically viable and cost-effective solution. Conventional CHGPs are limited to either stack-pack completions, which can incur high cost because of the considerable rig time required for multizone operations, or alternate-path single-trip multizone completions that treat all the target zones simultaneously, with one pumping operation. However, this method does not allow for individual treatment to suit reservoir characterization. The enhanced 7-in. multizone system can significantly reduce well completion costs and pinpoint the gravel placement technique for each zone, without pump-rate limitations caused by excessive friction in the long interval system, and without any fiuid-loss issues after installation because of the modular sliding side-door (SSD) screen design feature. A sump packer run on wireline acts as a bottom isolation packer and as a depth reference for subsequent tubing-conveyed perforating (TCP) and wellbore cleanup (WBCU) operations. All three zones were covered by 12-gauge wire-wrapped modular screens furnished with blank pipe, packer extension, and straddled by two multizone isolation packers between the zones, with a retrievable sealbore gravel-pack packer at the top. The entire assembly was run in a single trip, therefore rig time optimization was achieved. The two lower zones were treated with HRWPs, while the top zone was treated with an extension pack. During circulation testing on the lowermost zone, high pumping pressure was recorded, and after thorough observation of both pumping parameters and tool configuration, it was determined that the reduced inner diameter (ID) in the shifter might have been a causal factor, thereby restricting the flow area. This was later addressed with the implementation of a perforated pup joint placed above the MKP shifting tool. The well was completed within the planned budget and time and successfully put on sand-free production, exceeding the field development planning (FDP) target. The enhanced 7-in. multizone system enabled the project team to beat the previous worldwide track record, which was an HRWP treatment only. As a result of proper fluid selection and rigorous laboratory testing, linear gel was used to transport 3 ppa of slurry at 10 bbl/min, resulting in a world-first extension pack with a 317-lbm/ft packing factor.

Unconventional Drilling and Creative Solutions Delivered World Record a Multi-Laterals Fishbone all Legs Drilled, Accessed and Stimulated First Attempt - Case Study from Kuwait

2021 ◽  
Author(s):  
Nadir Farhi ◽  
Mohamed Ahmed Abdel Samie ◽  
Walid Saher Nouh ◽  
Hamdi Saber Ibrahim ◽  
Hadi Saad Al-Ajmi ◽  
...  
Keyword(s):  
Lessons Learned ◽  
Horizontal Drilling ◽  
Execution Phase ◽  
Multi Stage ◽  
Major Development ◽  
Creative Solutions ◽  
Tight Carbonate ◽  
Study Team ◽  
Open Hole ◽  
Long Time

Abstract Despite being the first area for oil to be found in Kuwait in mid 1930's, Bahra's oil production remained largely unexploited until 2015, when a major development campaign targeting one of its tight carbonate reservoirs through horizontal drilling and multi-stage frack completions was commissioned. Nonetheless, with the development and exploration initiatives underway, surface congestion is the primary challenge. As the number of wells increased the need for unconventional well profiles became more demanding. The multi-lateral fishbone approach was designed to have a total of four laterals with approximately 3000 ft each. Lessons learned from previous level-1 multi-laterals drilled in North Kuwait indicated that the primary challenge remained to be the ability to drill a smooth bore hole profile across the junctions to successfully re-access and stimulate all the drilled legs with coil-tubing to maximize production. Kuwaiti Operator Reservoir and study team were looking for an alternate solution to increase the production in Bahra using multi-laterals technics in the same reservoir to stimulate and sustain production in calcite reservoir. Historically only three wells were drilled experimenting challenges and failures to open hole sidetrack leading to have long time to complete the wells with maximum 3 legs as record including the mother hole. RST team asked to drill a well with 4 legs, each leg following the same azimuth with the condition to be 300 ft apart. The thorough planning exercise completed and the close follow-up to the approved design of service during execution phase resulted in the successful delivery of the first four legs fishbone in Kuwait with Zero Non-Productive Time. In addition to achieving all the geological targets, the smooth borehole profile helped ensure successful re-entry and stimulation of all four legs in the same run achieving the well challenge using the unique

scholarly journals A step change in safety performance through critical control management

2017 ◽  
Vol 57 (2) ◽  
pp. 539 ◽  
Author(s):  
Roberta Selleck
Keyword(s):  
Safety Climate ◽  
Oil And Gas ◽  
International Association ◽  
Step Change ◽  
Lessons Learned ◽  
Safety Performance ◽  
High Rate ◽  
Large Power ◽  
Work Related ◽  
Control Management

The oil and gas construction industry experiences a high rate of unnecessary work-related fatalities. The International Association of Oil and Gas Producers (IOGP) reported 54 fatalities in 40 fatal incidents in 2015. When assessing this against the use of IOGP Life-Saving Rules (LSRs), which contractors are required to adopt, the IOGP found that of the 40 fatal incident descriptions in 2015, at least 73% related to the IOGP LSRs. A program to apply a critical control management (CCM), or safety cased, approach to fatal hazards was trialled on construction sites in Australia and South Africa ranging from large power station constructions to offshore hook-up and commissioning to brownfields maintenance. The results demonstrated a step change in the safety performance occurred on projects where the CCM program was implemented. These projects have each demonstrated a significant improvement in recordable injuries, increases in hazard reporting and awareness, and almost complete elimination of high-potential incidents. Further investigation of the reasons for these results is the subject of a PhD project and includes: (1) understanding how the CCM program improves hazard awareness and decision making of frontline supervisors; (2) determining the effects CCM has on the safety climate of the organisation as detailed focus is applied on the effectiveness of controls that drive leadership decisions; and (3) investigating how CCM improves leadership at all levels of the organisation due to better information that allows tangible action to be taken to improve control effectiveness. This paper describes the progress of CCM program development, details present results and lessons learned, and provides a context for how CCM programs can be implemented in other organisations.

New Techniques Developed to Safely Unload and Test High Rate Offshore Sour Gas Well With 7-in Monobore Completions-Lessons Learned Gas Wells Offshore Sarawak Malaysia

2018 ◽  
Author(s):  
Azraii Fikrie Azraii ◽  
Adhi Naharindra Adhi ◽  
Thian Hui Chie Hui Chie ◽  
Claire Chang Claire ◽  
Ridzuan Shaedin Ridzuan ◽  
...  
Keyword(s):  
Lessons Learned ◽  
High Rate ◽  
Gas Wells ◽  
New Techniques ◽  
Gas Well ◽  
Sour Gas

First Multistage Fracturing of a Horizontal Well Drilled in a Tight Carbonate Reservoir in UAE

2021 ◽  
Vol 73 (06) ◽  
pp. 58-59
Author(s):  
Chris Carpenter
Keyword(s):  
Hydraulic Fracturing ◽  
Horizontal Well ◽  
Lessons Learned ◽  
Carbonate Reservoir ◽  
Thin Layers ◽  
Abu Dhabi ◽  
Total Production ◽  
Main Challenge ◽  
Horizontal Length ◽  
Tight Carbonate

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 203226, “First Multistage Fracturing of Horizontal Well Drilled in a Conventional Tight Carbonate Reservoir in an Onshore Field in the UAE: Challenges and Lessons Learned,” by Muhammad Aftab, SPE, Noor Talib, and Maad Subaihi, ADNOC, et al., prepared for the 2020 Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, held virtually 9–12 November. The paper has not been peer reviewed. The reservoir upon which this case study is focused is a tight, low-permeability carbonate reservoir with thin layers. The objective of the field case was to increase and sustain productivity of a pilot well consisting of an openhole completion. The complete paper summarizes the design processes, selection criteria, challenges, and lessons learned during design and execution phases. The study may provide a potential approach for selecting the proper hydraulic fracturing method and technique in similar cases. Introduction Reservoir X is divided into six layers. Layers X-3 through X-6 have reasonable porosity development; valid pressure points exist in X-3 and X-6. Pumpout was performed while collecting samples from X-3 and X-6, followed by short buildups. Production-logging-tool measurement was performed and found two major oil-producing layers across X-3 (60% of total production) and X-6 (40% of total production). The remaining intervals of the perforation were almost inactive. Petrophyscial and testing results of vertical Well A resulted in a decision to drill a horizontal oil producer (Well B) through Layer X-3. Well B was steered with a 2,220-ft horizontal length, out of which 1,930 ft was inside X-3 and 290 ft were above X-3 be-cause of a fault throw of 16 ft true vertical depth. The well was steered with a horizontal length of 2,080 ft in X-6. Well B was completed with a 3½-in. completion and horizontal section as an openhole. Matrix stimulation using coiled tubing was performed with 15% hydrochloric acid in Well B. The well ceased to flow after 2 weeks of declining production. Rapid pressure depletion was observed in Well B. Localized depletion around the wellbore was anticipated because of poor matrix/matrix connectivity. After comprehensive studies and risk assessments, the decision was made to recomplete Well B with a cemented fracturing string to perform hydraulic fracturing with the plug-and-perf technique. This technique will allow flexibility of stage count and stage spacing and a multi-cluster design to maximize the stimulated reservoir volume (SRV) along the upper, middle, and lower layers. In addition, the operator and service provider collaborated to enhance this design through a zero-overflush technique with diverting agents. The complete paper provides a detailed discussion of the core measurement and 1D mechanical Earth model used in the hydraulic fracturing design. Hydraulic Fracturing Design The main challenge in fracturing Well B was to ensure that the fracture generated is contained within the reservoir. Well B is completed in two layers (X-3 and X-6). The bottom part of the well is in X-6 and close to another underlying reservoir (Fig. 1).

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