Outstanding Production Performance Through the Extreme-Lean Profile Well Design: an Example of Drilling Operational Excellence that Allowed Reaching the Reservoir Target with a Bigger Hole Size in a Mature Field

2014 ◽  
Author(s):  
Alessandro Puliti ◽  
Claudio Molaschi ◽  
Alberto Maliardi ◽  
Giuseppe De Grandis
Keyword(s):  
Production Performance ◽  
Hole Size ◽  
Well Design ◽  
Mature Field ◽  
Operational Excellence

Determining Hole Size and Washout by Running a Fluid Caliper, for Cementing Purposes

2021 ◽  
Author(s):  
Jason Scott Ellison ◽  
Charles Ralph Ellison ◽  
Mike Davis ◽  
Carl Bird ◽  
Ryan J. Broglie ◽  
...  
Keyword(s):  
Human Error ◽  
Best Practice ◽  
The United States ◽  
Accurate Estimation ◽  
Drilling Fluids ◽  
Hole Size ◽  
Permian Basin ◽  
Lost Circulation ◽  
Well Design ◽  
Downhole Tool

Abstract This paper describes the procedure to perform a fluid caliper and how by using fluid dynamics concepts, average hole size can accurately be determined, helping to derive the amount of hole washout and the appropriate amount of cement needed to circulate or achieve desired cement height. This process has been successfully performed on over 40,000 Permian Basin wells in West Texas and Eastern New Mexico, as well as numerous other basins in the United States. This includes vertical, directional, and horizontal wells of varying hole sizes and depths, from surface to production hole. This paper will provide real world examples, discussion of geological formations encountered, drilling fluids used, and the ultimate benefit a fluid caliper provided each operator through the accurate estimation of cement volume for the reduction of waste and satisfaction of well design and regulatory requirements. This paper will demonstrate that fluid calipers add to the operational efficiency of most drilling operations and should be considered a "Best Practice" for most drilling programs as their use can greatly limit the need to remediate a cement job necessitating additional downhole tool runs, wasting additional valuable rig time. Also, to be addressed are the limitations of fluid calipers including lost circulation, turbulent flow, and human error. Cementing is an integral part of the process to ensure wellbore longevity, requiring increased attention. Field practice of pumping nut plug, dye, or other markers to estimate required volumes is outdated and inaccurate. This paper will clearly identify the reasons why the modern fluid caliper is aligned with today's heightened focus on ESG. Environmentally, fluid calipers determine the proper amount of cement to prevent waste. Regarding safety, fluid calipers help ensure the operator pumps accurate cement volumes to cover corrosive and/or productive zones to prevent unwanted annular influx, and referring to governance, fluid calipers help the operator pump adequate cement volumes to satisfy well construction regulations.

Successful Installations and Predictable Performance of Solid Expandable Drilling Liner in Greater Ekofisk Field, Offshore North Sea

2021 ◽  
Author(s):  
Eko Awan Fitnawan ◽  
Bjørn Holien ◽  
Harald Nevøy
Keyword(s):  
Design Strategy ◽  
Gas Content ◽  
Base Case ◽  
Hole Size ◽  
Lost Circulation ◽  
The Past ◽  
Track Record ◽  
Well Design ◽  
Collapse Resistance ◽  
Installation Time

Abstract Drilling the lower overburden section in specific parts of the Greater Ekofisk Area (GEA) fields can be very troublesome. Wells in these parts may intersect shales with high gas content in the upper section (requiring high mud weight) and unstable zones with massive lost circulation risk (requiring low mud weight) near the base of the interval. These challenges have raised the need for a contingency drilling liner to "split" the section in two parts. Rather than changing the basic well design, the operator fronted the development of an 8-5/8″ expandable drilling liner with high collapse resistance for this purpose. This string provides 8.514″ post-expansion drift ID that accommodate an 8 ½″ bit size for the reservoir section, which is critical for GEA well design strategy. In the past five years, the operator has successfully installed 31 800 ft of 8-5/8″ expandable liner in 27 different wellbores with near perfect track record. The average liner length installed is 1 140 ft per wellbore, with an average installation time of 2.8 rig days. The solid expandable tubular (SET) drilling liner has been utilized both as part of the planned well design and as contingency liner. It has, on occasions, been worked down with parameters outside the stated specifications and still been successfully expanded afterwards. The 8-5/8″ expandable liner is now a proven system and has been one of the key enablers to achieve well objectives by maintaining hole size in a predictable manner. It provides a better drilling window for reservoir drilling and reservoir liner cementing compared to a conventional 7-3/4″ liner alternative. It also enables further contingency solutions in case other difficulties arise in the reservoir section. This technical paper describes how the operator in the overcame a significant geological challenge by working with an expandable pipe supplier to develop a unique size and strength of expandable liner that fits with the base case GEA well design. The paper also reviews the installation experiences, associated risks, performance, and key learnings with expandable liners.

Well Design and Successful Field Installation of Openhole Sand Control Completions with Acid Stimulation in a Highly Deviated Well in Vietnam

2016 ◽  
Author(s):  
Hung Vu ◽  
Son Tran ◽  
Trang Nguyen ◽  
Bharathwaj Kannan ◽  
Khoa Tran ◽  
...  
Keyword(s):  
Control Device ◽  
Production Performance ◽  
Fluid Loss ◽  
Horizontal Section ◽  
Well Completion ◽  
Well Design ◽  
Mud Cake ◽  
Sand Control ◽  
Open Hole ◽  
Oil Rim

ABSTRACT Application of openhole sand control technology is becoming mandatory in the field, particularly with the given uncertainty in geomechanics, challenges to wellbore integrity while drilling, and sand production during the life of the well. The completion equipment readiness and success of the installation can be challenging in the event of extending the horizontal section to accommodate geological heterogeneity and maximizing well productivity. This paper discusses operational excellence recorded in Well A, in the Thang Long Field, offshore Vietnam, from well design perspectives ensuring maximum reservoir contact to outcome of well completion. The well was targeted in the Oligocene reservoir, a thin oil rim with large gas cap overlay, and required drilling and completion for 1126 m horizontal length of 8 1/2-in. open hole. The completion design included multiple swellable packers for isolation of unwanted zones, 6 5/8-in. basepipe sand screens for the production zones, and a fluid loss control device to help prevent undesirable losses. Several torque and drag simulations were performed to help predict potential threats that could be encountered during completion string deployment or during space out of the inner wash pipe string. One apparent challenge of this completion design was to deploy the lower completion string to total depth (TD) per stringent reservoir requirements, resulting in an approximate 1126 m length of the string in the horizontal section. Another task was to facilitate manipulating 1130 m of wash pipe inside the completion string to locate the seal assemblies accurately at the corresponding seal bore extension positions for effective acidizing treatment. Although these were long sections of completion string and wash pipe, the quality of acidizing stimulation to effectively remove mud cake should not be compromised to ensure positive production rates. During operations, the completion string was run to target depth without any issue, and the wash pipe was spaced out and manipulated correctly. These operations subsequently led to a successful acidizing treatment and the proper closure of the flapper type fluid loss device. The completion design and operation were concluded successfully, significantly contributing to field production performance to date. The novelty of the completion design and installation is the ability to deploy an 1126-m lower completion in long, highly deviated and horizontal openhole section coupled with acid stimulation in reasonable time and as per plan.

GEOLOGICAL EFFECTS ON PRODUCTION PERFORMANCE OF OPEN PIT COAL MINES

2017 ◽  
Vol 12 ◽  
pp. 96-108
Author(s):  
E.L. Karibzhanova ◽  
◽  
A.E. Safronov ◽  
O.O. Skryabin ◽  
V.V. Semenyaka ◽  
...  
Keyword(s):  
Coal Mines ◽  
Production Performance ◽  
Open Pit
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