bluuebunny/crossref_metadata_2025_split huggingface dataset:
Numerical Analysis on the Interaction between Two Zipper Frac Wells Using the Continuum Damage Method
Authors: Shen Xinpu 
Published: February 2015

Description
A numerical simulation has been performed on the formation fracturing process under hydraulic stimulation. The Continuum Damage method has been used for modeling of formations fractures. A coupled calculation of hydro-mechanical problem using the three-dimensional (3D) finite-element method (FEM) is also introduced.

Application
This model was used to estimate the results of a zipper-frac design from stimulation measurements of two horizontal wells in a tight-sand field.

Results, Observations, and Conclusions
The parameter calibration of the continuum damage model used here was performed with measured micro-seismic data of fracture propagation under injection stimulation obtained from an offset well. The initial damage value was assigned to the formation before injection stimulation simulation to model the effect of natural fractures. With a given geometry (100 m width, 100 m length, and 20 m thickness), which has two injection sections, damage evolution was calculated under a given value of injection fluid flow rate. The model is made simple as a result of geometrical symmetry.
Numerical results of the 3D-coupled hydro-mechanical problem are presented, which include:damage distribution between two injection stages after stimulation. The value of the continuum damage variable here represents both natural and induced fractures around a horizontal injection well for a specific injection pressure;The distribution of pore pressure and maximum principal strain components are analyzed and shown;damage variable develops in a similar pattern to that of maximum principal strain;comparison of damage distribution and stimulated formation volume for two different injection measurements.

Significance
This work shows that interaction between two neighboring stimulation stages can increase the effective fracture length by overlapping the front area of the damage zones. This work shows that the coupled hydro-mechanical finite-element model is an effective tool for estimating stimulated volume in tight sand reservoirs.
Remote Control Systems Advance Offshore EPRS
Authors: Lim George 
Published: February 2015

Description of the Material
Integrity management programs are used to prevent, detect and mitigate integrity threats that occur throughout a pipeline's lifecycle, from construction through operation to decommissioning. But unfortunate events occur, causing pipeline failures that jeopardize people, the environment and business. Offshore operators often establish a dedicated Emergency Pipeline Repair System (EPRS) to effectively respond to - and recover from - an incident. This paper describes several remote control systems that contribute to EPRS capacity.

Application
Attributes of an effective EPRS include its ability to cover 1) all incidents, by having a comprehensive inventory of the right tools, 2) the full lifecycle of pipeline assets, from design to decommissioning, and 3) all operating areas, including deep water or where unsafe diver conditions exist.

Results, Observations and Conclusions
T.D. Williamson (TDW) has developed several remote-controlled tools that may assist in establishing optimum response capacity. Inserted in the pipeline in strategic positions along the suspended section during pipe laying, the SmartLay™ tool acts as instantaneous barrier against flooding in case of an inadvertent wet buckle, protecting the vessel from undue forces from the heavier flooded pipe and preventing costly and time consuming dewatering and re-commissioning of the just-laid pipeline. The Clamp Installation Tool (CIT) is a lightweight, readily deployable tool run with standard work class ROVs for the installation of any size repair clamps or hot tap tees from any third party supplier. Combined with the CIT for tee installation, the remote-controlled Subsea 1200RC Tapping Machine offers a hot tap solution that not only facilitates deep water repairs, but also reduces risk to personnel and increases efficiency. The SmartPlug® tool is an un-tethered inline tool for isolation management of a range of repair scenarios where intrusive plugging is less desirable. It is remotely controlled via thru-the-wall communication by SmartTrack™ technology, which can also act as stand-alone pig tracking equipment.

Significance of Subject Matter
The anti-flooding SmartLay™ Tool can cover the construction phase; the Subsea 1200RC Tapping Machine and Clamp Installation Tool assist deep water intervention and repair during operations; SmartPlug® technology offers isolation management; and SmartTrack™ pig tracking affords integrity management.
Composite Abrasive Technology: A Key Part of New Sustainable Commissioning & Process
Authors: do Nascimento Bernardino Nilton , Ramli Mazrin 
Published: February 2015

In what isbeing called the first Oil and Gas "Sustainable Commissioning" project, advanced composite abrasives (ACAs) is beingused to help conserve precious resources. A recent field study and projectconducted by Odebrechtcommissioning manager, Bernardino Nilton do Nascimento revealed key points thathave already saved water in a region with unprecedented pressure to conserve. The core ofthis sustainable solution includes ACAs and a "pig" system, which were firstfield tested then used in Petrobras Refinaria Abreu de Lima (Brasil). Theproject entailed blast-cleaning cooling lines, hydrostatic testing and thennon-destructive testing in their TR-86 (Unity 32) Cooling Tower. Typically, residual products are removed (1) toassure efficient flow though refinerysystems and (2) to protect operating equipment. A rinsingsolution is passed through all pipes and then to a water treatment station. Testresults provided groundbreaking observations for Nascimento and PetrobrasProject Manager, Ricardo dos Santos Ramos:No water was used during ACA blasting it was concluded that 200,000 liters (or53,000 gallons) of water was saved on Unity 32 Cooling Tower alone.Water-relatedsteps (e.g. conditioning, special treatment, disposal anddisposal) were eliminated.Cleaningoperations on commissioning projects would have included seven steps:waterconditioning,water washing,chemical rinsing,drying,applyinglining/pipe treatment,water treatmentdisposal.
During ACAblasting, the number of steps dropped to two? (1) blasting pipe internals(2) applying the appropriate treatment via pig.
Nascimentoand Ramos extrapolated savings of 16 million liters (4.3 million gallons) ofwater by using ACA for all refinery line cleaning during the commissioning.
Withtesting and the first lines completed, Nascimento and Ramos then proceeded toother parts of the refinery commissioning project, continuing to usedust-suppressing ACA technology. They also found that sensitive equipment likecompressors and pumps had added reliability. This paperwill outline field testing and project data, comparing common cleaningoperations to the "Sustainable Commissioning" process. Results will convey environmental and economic significance and the carryoverto similar offshore applications - during commissioning and maintenance of internalpiping systems.
Subsea Development of Marginal Deepwater Fields
Authors: Samad J. 
Published: February 2015

Development of greenfield deep water oil and gas fields are generally known to be expensive, compared with conventional shallow water fields development. Having marginal fields in deep water only compounds the challenge to development.
This presentation aims to discuss the challenges associated with developing marginal gas fields in deep water. It however centers primarily on the subsea portion of the development.
Marginal gas fields are typically &lt; 500 bcf, and are best developed when there is an opportunity to combine a number of such marginal fields for a clustered development. However, invariably, each field has different characteristics (volume, pressure, composition) and hence requires careful planning to ensure constant flow to production facilities.
The presentation will thus elaborate on the use of software tools such as Maximus for phased field development planning to ensure base load gas production throughout the project lifetime.
At FEED stage, the subsea facilities and topsides facilities are typically carried out by separate design contractors, involving an interface at the surface that needs to be managed well to ensure optimum overall system design for smooth economical operation.
In the case of developments utilising FLNG the interface issues can become rather complicated when the subsea facilities design team at FEED stage has to interface with multiple FLNG FEED contractors participating in a design competition.
The challenges centred round the subsea development include Field Layout planning, FPF interfaces, subsea CAPEX, Flow Assurance, Hardware limitations (qualification), Technology (applications of dual directional subsea wyes, and subsea pigging launcher/receivers). The presentation will also elaborate on the use of other software tools such as ArcGIS for pipeline route layout planning and optimisation, and Star-CCM Plus for sand erosion CFD (Computational Fluid Dynamics) modeling.
Interval Pressure Transient Test and Stress Testing in Coal Bed Methane Using Dual Packer Formation Testers: Case Studies from Indonesia
Authors: Weatherall Glyn , Halinda Debby , Daungkaew Saifon , Suriyanto Olivia , Mas Cholid , Islam Anzar 
Published: February 2015

Significance of Subject Matter
Coal Bed Methane (CBM) has become one of the most important unconventional resources for today petroleum industry since its discovery in many countries including Indonesia. The main challenge for CBM fields is a proper reservoir characterization in coal matrix, cleat and shale layers. Another main challenge is a variation in reservoir productivity from zone to zone. Formation evaluation for this unconventional reservoir is not as straight forward because the evaluation program needs to be adjusted to obtain enough reservoir information for an effective field development plan.

Application
The Dual Packer Formation Testers (FT) can be used to test zones where matrix porosity is too low for a single probe FT such as carbonate and fracture basement reservoirs. However, the use of dual packer FT remains quite a challenge due to time per station, tool sticking risk, and limited packer intervals. This paper reviews the use of Dual Packer FT to evaluate reservoir properties in one of the CBM wells in Asia.

Description of the material
This paper presents the use of Dual Packer FT for an Interval Pressure Transient Test (IPTT) for reservoir pressure, fluid sampling, zone permeability, and also for a stress testing applications. This paper will be more focused on the stress testing technique using Dual Packer FT. This "micro-frac" application in CBM wells plays an important role in providing shale layers' stress parameters such as a fracture treatment design and an optimal completion design. However, it also has its operational challenges associated for pre-job planning.

Results, Observations, and Conclusions
This paper presents a systematic integration between pressure transient analysis and fracture diagnostic plots utilizing a G-function plot, as well as a Square-Root time plot in this smaller scale of fracturing operations. The output of the analysis including initial breakdown pressure, closure pressure, fracture propagation pressure, initial shut-in pressure, and shale permeability will be discussed and compared with full scale fracturing, drilling leak off tests, and modeling results from geomechanics study. This paper will also address technical and operational aspects of the Dual Packer FT operation in this unconventional reserve.
Development of a PDC-Tricone Hybrid Technology to Solve Drilling Problems of Surface Holes in North Africa
Authors: Moujbani Walid , Aliko Enis , Chaabane Naceur 
Published: February 2015

A major oil company started a drilling campaign onshore South Tunisia, where wells require long, 16-in. diameter surface holes to be drilled through a variety of lithologies that present several drilling challenges..
The challenges in this section start with mud losses that usually require controlled rate of penetration (ROP) to manage the volume of cuttings. The second drilling challenge comes while drilling through clays, which can cause balling of the bit and stabilisers. The third and most difficult drilling challenge is presented when Pyrite and sometimes Chert nodules are encountered..
To overcome these challenges, a novel PDC-Tricone hybrid bit technology was designed and tested as a potential solution. The bit's combined cutting structure can drill with the efficiency and aggressiveness of a PDC bit and handle a hard nodular formation like a Tricone bit, without suffering any damage. The bit enabled the operator to drill the entire section in a single run and saved more than 55,000 USD on the first well. Following this run, the bit was modified to increase its aggressiveness and durability and was run in more wells, confirming the initial success..
As the operator and the service company became more confident that the hybrid bit could drill the entire section without suffering damage, the operating parameters were raised to gain higher ROP. Additional improvements were made to adapt to the more demanding conditions, and the PDC-Tricone hybrid bit matched the performance of conventional PDC bits, generating financial gains for the operator..
Based on the success of this campaign, the same bit type was proposed to other operators, drilling offshore Morocco, with the ambitious objective of drilling a long chert-bearing section in one run.. This paper describes the development of the PDC-Tricone hybrid bit design, the results of lab testing conducted during this development, design iterations, and the results of its application in North Africa. Details performance compared to conventional PDC bits and results of offshore applications will be also presented.
Reliable Lashing Lines Fatigue Monitoring for a Tender-Assisted Drilling Unit
Authors: Prislin Igor , Chabot Luc , Dean Linda H. , Liu Tuanjie , Ye Wei 
Published: February 2015

Description of the Proposed Paper:
The paper describes a reliable, effective, and practical, solution for monitoring and reporting fatigue damage of lashing lines on the Murphy Kikeh DTU. The solution is based on a ton-cycle method that uses measured line tension and calculated number of cycles when the critical line segment enters and exits the sheave. The method is calibrated using real data and then implemented on-board of the DTU. It provides indication of the integrity endurance level of a critical lashing line. The same method helped in re-designing the original lashing system, which reduced wear and prolonged the fatigue life by a factor of four.

Application:
The integrity and the fatigue life of the lashing lines that keep TAD unit closely connected to the DTU is carefully and continuously monitored by the Integrated Marine Monitoring System.
Fatigue life of a line is monitored through cumulative ton-cycle value. When this value approaches the calibrated threshold, the line can be replaced at the most convenient time, avoiding unpleasant surprises such as when a line breaks during production, making the production safer and more cost effective.

Results, Observations, and Conclusions:
The lashing line ton-cycle method has been integrated with the other marine and structural monitoring parameters on board of the Kike DTU for several years.. When the values approach the 100% of the absorbed fatigue life, the results are displayed on the operator screens in the control room indicating that the line is in a critical condition with a high expectation to break. This indication helps the operator to plan, prepare and conduct the line maintenance or replacement in a timely manner and at the most convenient time without interrupting critical phases of operation. This process became a standard process for the lashing line integrity monitoring and maintenance and it has been working reliably for more than three years.

Significance of Subject Matter:
Developed and implemented ton-cycle method shows a simple yet effective and reliable method for increasing overall the safety of operations, as well as preventing costly interruption of normal production on the Kikeh DTU and the nearby TAD unit.
Pipe End Round Forming Equipment and Control System - The Fundamental Solution for Reducing Welding Defects in Offshore Pipeline Constructions -
Authors: Kishiguchi Tetsuya , Hosada Hiroyuki , Ikuno Yasuyukiy , Ikezaki Toru , Akasaka Masayoshi , Torii Tadashi 
Published: February 2015

In offshore pipeline constructions, high productivity is required to minimize pipe laying cost. One of the most significant methods for achieving higher productivity is to reduce the welding defects, which lead to repairs.
Recently, the acceptable level of welding quality, especially the root pass, becomes higher and higher. This means minimizing misalignment between both pipe ends is required to get rid of welding defects triggers.
On the contrary, the tolerances of commercially manufactured pipes have not been revised and shape fluctuation between both pipe ends is not ideal for welding condition. Various line-up clamp systems of pipes have been employed, however their control range is too limited to realize ideal alignment. To solve this problem fundamentally, authors have developed a pipe end forming equipment, to aim at perfect alignment between both pipe ends for girth welding. Applying the equipment, pipe ends are equalized in the shape, i.e. both diameter and roundness, and are fitted easily with each other for welding.
The pipe end forming equipment has two additional features. One is Compactness. The compact design enables its easy installation onto the existing barge with minimum modifications. The other is quick processing. The processing duration does not cause any interruption for the cycle time of pipe laying operation.
This shape equalization between both pipe ends leads to not only elimination of welding defects but also reduction of pipe fitting time prior to welding. We believe that the equipment will highly contribute to improve pipe laying productivity.
New Advances of Formation Testing in the Extreme Tight Gas Reservoirs using new 3D Radial Probe: Case Study in South China Sea
Authors: Cai J. , Guo S. , Gao Y. , Chen J. , Xian C. , Tellapaneni P.K. , Zhang T. 
Published: February 2015

CNOOC is operating in YingGehai Basin and QiongSouthEast Basin of South China Sea. Formation testing has been routinely used by this operator in field exploration to confirm hydrocarbon presence, define the hydrocarbon type as well as getting PVT samples. Due to the high cost of DST operation in the offshore environment, formation testing is considered as the main testing method to test the small to medium size sand bodies. And the result is accepted to claim reserve of hydrocarbon.
As the recent offshore exploration has focused more on deeper formation where the sand permeability is between low to ultra-low, the pressure pretest mobility is easily lower than 1md/cp. In some particular formation, the formation mobility is even lower than 0.1md/cp. For this type of permeability of sand, testing becomes very difficult and getting fluid sample to claim reserve becomes a huge challenge. If the formation tester fails to obtain the samples, very often the later DST operation would not achieve a success.
A new probe module of formation tester has been introduced to the industry early 2013 and it has been designed to perform formation testing in low permeability environment. Especially it could apply a much higher drawdown than previous technology to move the tight hydrocarbon.
In this paper, a few cases will be presented to demonstrate how this new probe work in Yinggehai and QiongSouthEast basins fluid sampling operation where we sampled successfully at formation with the mobility is less than 0.1md/cp. With this result, great amount of reserve can be claimed and this new probe has been considered as the unique solution of testing these formation as well as predicting the possible production capability..
Small, Lightweight CTU Helps Enhance Production from Limited-Space Offshore Platform
Authors: Sundramurthy Deenadayalan , Dean Gregory , Stanley Frederick , Terry Adrian , Abidin Osman Zainal 
Published: February 2015

A new lightweight, small-footprint coiled tubing unit (CTU) has been developed to enable CT for a broad spectrum of well service applications. The technology could substantially reduce well intervention costs, logistical support and risk exposure and can be applied to operating environments worldwide, both onshore and offshore. Wells that were once considered plug-and-abandon candidates due to cost, technical challenges or accessibility may now be candidates for small CTU solutions.
The motivation for one Malaysia operator to use the small CTU was the limited operating capability of their platform i.e. small crane and limited deck space / weight restrictions. A lower zone in one of the operator's wells became inaccessible after damage occurred to a permanent tubing patch used to abandon an upper zone. Intervention methods were narrowed down to the small CTU or tractor-deployed milling.
The small CTU was chosen to perform milling runs with 1-in. CT and motor. After several milling passes through the 2.2-in. ID tubing patch, access to the lower zone was accomplished. Perforation on slickline was unsuccessful and the 1–11/16-in. perforating guns were then successfully deployed on the 1-in. CT and the well perforated.
Numerous challenges will be reviewed including work with small 1-in. OD pipe, small motors and working inside a restricted completion with high dogleg severity and 70 degree hole angle. A total of 23 runs, including 14 perforation runs, were performed and the entire job was completed safely and without any major issues in 20 days.
The intervention was extremely successful with the well coming online at 15 MMSCFG/day. The intervention has allowed the operator to recover reserves that would have otherwise been abandoned due to expensive workover costs. Additionally, this job is the first of its kind ever performed in Malaysia and has opened up additional opportunities in shallow or deepwater installations.