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Collaborating Authors
Drilling fluid management & disposal
A Case Study of Real-Time Drilling Optimization to Improve Well Delivery through Enhancing Drilling Rates and Identifying Invisible Lost Time to Improve Performance
Zakariya, Rafik (Halliburton) | Zein, Alaa (Halliburton) | Diab, Emad (Halliburton) | Lotfy, Amr (Halliburton) | Marland, Chris (Halliburton) | Obaidli, Yaqoub Yousif (Zadco) | Braik, Haitham Ali (Zadco) | Amin, Mohamed Sameer (Zadco) | Attalah, Mohamed (Zadco)
Abstract As the oil and gas industry expands into evermore challenging environments with more complicated processes and designs, minimizing well cost and ensuring the best use of resources has resulted in an increase in the engineering planning and field-execution requirements. Drilling optimization has changed from simply improving the rate of penetration (ROP) to analyzing all aspects of the drilling process by establishing an integrated workflow that enables different engineering departments to plan and execute the well. In this case history, the operator’s challenges included vibration in horizontal sections, hydraulics, and wellbore integrity concerns resulting from narrow mud weights available to minimize reservoir damage and to control pore pressure. Drilling optimization also includes measuring and improving operational efficiency and consistency. Many activities are required in a drilling operation, and the inefficiency of these activities increases well costs. This inefficiency can be described as invisible lost time (ILT), which has been shown to contribute to up to 15% of total well cost. It exposes open holes to longer elapsed times which causes hole problems, especially in reactive formations. This case study takes a holistic look at the drilling performance and efficiency improvements that can be made by planning, modeling, and introducing a collaborative drilling engineering team with a real-time field execution team to analyze drilling challenges and address those challenges for future developments.
- Well Drilling > Drilling Operations > Drilling optimization (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- (4 more...)
Investigation Of The Stability Of Hollow Glass Spheres In Drilling Fluids In Diverse pH Environments And Assessment Of Potential Field Applications In Saudi Arabia
Alawami, Mohammed B. (Saudi Aramco) | Al-Yami, Abdullah S. (Saudi Aramco) | Wagle, Vikrant B. (Saudi Aramco) | Alhareth, Nasser (Saudi Aramco)
Abstract Low-density water-based drilling fluids formulated with hollow glass spheres (HGS) offer an attractive drilling method. HGS are incompressible lightweight additives with the capability to reduce mud weight down to 41.0 lbm/ft (5.5 lbm/gal). Several pressure ratings of HGS are available, and selecting the appropriate rating is essential to avoid formation damage and lost circulation in near-balance conditions. Failure of the spheres could thus lead to catastrophic results. The objectives of this paper is to evaluate the stability of inhibited water-based drilling fluids formulated with HGS in diverse pH environments, and assess their potential application in Wasia formations in Saudi Arabia. Wasia formation is composed of middle cretaceous clastic rocks with layers of sandstone, shale and occasional limestone. Wasia is an aquifer with a thick unit that crops out in central Najd with a slight eastward dip (Powers et al. 1966). The pressures of Wasia correlate to equivalent mud weights (EMW) of 51—58 lbm/ft. This range of EMW is lower than that of water, and the use of conventional mud systems could introduce several operational difficulties due to the high hydrostatic pressure they create. The implementation of HGS-based lightweight fluids would lower the hydrostatic pressure in the wellbore, thus eliminating or reducing the frequent loss of circulation experienced in Wasia. HGS-based fluids could also provide greater protection of underground water resources, improve rate of penetration (ROP), and reduce or eliminate differential pipe sticking. We conducted comprehensive analysis of HGS performance in various pH environments to assess their stability in drilling fluids. Mud characteristics and rheological properties were examined before hot rolling (BHR) and after hot rolling (AHR) to determine the effects of high pressure and high temperature (HPHT) on the system. The duration at which the samples were exposed to HPHT conditions varied from 1 to 4 days to understand the behavior of the mud over time. In addition, two typical formulations were prepared using HGS and conventional additives to evaluate their properties and compare them to the American Petroleum Institute (API) standards. Hollow glass microspheres were found to be stable in the pH conditions of drilling operations (pH ~9), with a maximum density variation of 0.5 lbm/ft. At higher pH levels (pH >11), the spheres experienced fractional dissolution due to the reaction of the added NaOH with borosilicate glass. In pH ranges lower than 4, the spheres were found to be extremely stable. The inhibited water-based fluids formulated with HGS produced favorable rheology and stable mud characteristics before and after exposure to the actual downhole temperatures of Wasia formation.
- North America > United States (1.00)
- Asia > Middle East > Saudi Arabia (1.00)
- South America > Venezuela > Lake Maracaibo > Maracaibo Basin > Ayacucho Blocks > Motatan Field (0.99)
- Asia > Vietnam > South China Sea > Cuu Long Basin > Block 9-2 (0.99)
- Asia > Middle East > Saudi Arabia > Arabian Gulf > Arabian Basin > Arabian Gulf Basin > Wasia Formation (0.99)
- (2 more...)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
An Integrated Approach to Improve Safety Margins While Drilling – A Case Study from Ha'py Field, Offshore Nile Delta
El Waseef, Mohamed (BP-PhPC) | Bentham, Peter (BP) | Wild, Lorraine (BP) | Mansour, Mohamed (BP) | Ismail, Saher (BP) | El Kasrawy, Gamal (PhPC) | Raslan, Samir (PhPC) | Mahmoud, Moustafa (PhPC)
Abstract This study has been focusing on planning wells, which target lower Pleistocene reservoirs below a depleted Ha'py gas field. Many Non Productive time events (NPT) have been anticipated, and the challenges of losing wells and running over budget have been considered as major risks in targeting the deeper prospects. Years of production from the main Pleistocene A20 reservoir has resulted in significant pressure depletion, while underlying largely-undeveloped Pleistocene reservoirs appear to be very promising they remain at or close to virgin conditions. In addition, the position of the platform at the centre of the field has made it necessary to drill highly-deviated wells to access remaining reserves at the crest of the field. Detailed planning and close collaboration between the PhPC (Pharaonic Petroleum Company) subsurface and drilling teams has been necessary to understand the geological and geomechanical properties of the key formations. This has helped in selecting appropriate mud rheology and mud additives in addition to ensuring good drilling practices that maximise safety and success. The combined effects of depletion and low rock strength make it effectively impossible to drill the A20 interval with the mud weights required to minimize well bore instability. As a result, stress cage additives were employed in the drilling mud in order to reduce the potential for losses due to the large overbalance against the depleted sand. Modeling prior to drilling suggested this application lay close to the technical limit of the stress cage methodology, and was beyond anything previously attempted within the Pleistocene reservoirs in the offshore Nile Delta. Careful execution meant we were able to successfully drill through the depleted zone, and as a result of this work, we have been able to deepen recent wells to access underlying gas resources. This success has allowed us to reduce NPT while ensuring safe well operations.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.34)
- Africa > Middle East > Egypt > Nile Delta > Nile Delta Basin > Ras El Barr Concession (0.99)
- Africa > Middle East > Egypt > Gharbia Governorate > West Ismalliya Basin > West Gharib Concession > Asl Formation (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Block 29/5b > Elgin Franklin Field > Fulmar Formation (0.94)
- (2 more...)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Well Planning (1.00)
- Well Drilling > Pressure Management > Well control (1.00)
- (5 more...)
Abstract When cementing liners, the cement must develop compressive strength at the top of the liner before drilling is resumed. Sometimes at high temperature wells, it can take us up to 2 days just waiting for compressive strength development at top of liner conditions. This problem is common when cementing long liners in high temperature wells. An earlier study done by Yami et al. (2007) showed the development of two new retarded systems. The first system is used for non-latex cements for wells that do not show indications of fluid flow. The second cement system includes latex and is recommended for liners with potential for fluid flow. The new retarder systems were effectively applied in a well in Red Sea. This paper discusses the non-latex system field application and summarizes lessons learned. The field application was done by using sodium salt and alicyclic acid with aminated aromatic polymer in combination with sodium salt of organic acid and inorganic salt and aromatic polymer derivatives to cover differential temperature of more than 100 °F.
- Asia > Middle East > Yemen (1.00)
- Asia > Middle East > Saudi Arabia (1.00)
- Africa > Middle East > Egypt (1.00)
- Africa > Middle East > Djibouti (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.93)
- Asia > Middle East > Kuwait > Ahmadi Governorate > Arabian Basin > Widyan Basin > Greater Burgan Fields > Burgan Field > Wara Formation (0.98)
- Asia > Middle East > Kuwait > Ahmadi Governorate > Arabian Basin > Widyan Basin > Greater Burgan Fields > Burgan Field > Sargelu Formation (0.98)
- Asia > Middle East > Kuwait > Ahmadi Governorate > Arabian Basin > Widyan Basin > Greater Burgan Fields > Burgan Field > Ratawi Formation (0.98)
- (6 more...)