OTC panelists were excited at the potential of deepwater exploration offshore Mexico and believe that opportunities there could eventually drive a big new wave of activity. One of the oldest deepwater platforms in the Gulf of Mexico has become a profit-leader for the oil major during this downturn and is now a model for the company’s other floating assets. The new economic environment known as “lower for longer” has had no small effect on offshore safety, said a panel of experts at the 2017 Offshore Technology Conference. Panelists at the Offshore Technology Conference largely doubted that the oil and gas industry is making full use of digital technology for fundamental transformation. Companies are rethinking offshore developments and in a very tough market are finding innovative ways of bringing some projects forward.
As the hunger for data grows, long stepouts become more common, and fiber communication becomes standard, the use of fiber in subsea oil and gas fields is set to increase. The paper provides a fast-track approach to perform screening assessment of multiple subsea concepts. Technologies are being developed that have the potential to support marine mining in all stages from prospection to decommissioning. When two engineers lost their jobs during the industry downturn, they used the misfortune as an opportunity to develop an innovative concept that aims to make it a lot easier to move subsea gas long distances. Currently, the state of the art for subsea well control is based on hydraulic technology.
Africa (Sub-Sahara) Eni Congo discovered oil at its Minsala Marine 1 well offshore the Republic of the Congo in Marine XII Block 12 km from the operator's recent Nené Marine discovery. Minsala intersected 420 m of gross pay and encountered light oil in a Lower Cretaceous presalt sequence. The well reached a total depth of 3700 m. Eni (65%) is operator, with state-owned partner SNPC 25%), and New Age (African Global Energy) Limited (10%). SOCO EPC's Lindongo X Marine 101 Well (LXM-101)--located offshore the Republic of Congo in Marine XI Block--encountered oil in a clastic sequence of the Djeno sands, with early log interpretation indicating approximately 50 m of gross pay.
Africa (Sub-Sahara) Eni finished a production test on its Minsala Marine 1 NFW well, located in Marine XII block, 35 km offshore The Republic of the Congo. During the test, the well delivered natural flow in excess of 5,000 B/D of 41 API crude and 14 MMcf/D of natural gas from a 37-m opened section of the discovery's 420-m column. Eni (65%) is operator, with state-owned partner SNPC (25%), and New Age (African Global Energy) Limited (10%). Asia Pacific CNOOC started natural gas production from the Panyu 34-1/35-1/35-2 project at the Pearl River Mouth basin in the South China Sea. Main production facilities for the three gas fields include one comprehensive platform, two sets of underwater production systems, and 13 producing wells. Two wells are producing a total of 21 MMcf/D of gas. The project is expected to reach peak production of 150 MMcf/D.
Africa (Sub-Sahara) Eni started production from the Nené Marine field, which sits in the Marine XII block in 28 m of water, 17 km offshore the Republic of the Congo. The first phase of the field produces from the Djeno pre-salt formation, 2.5 km below the ocean floor at a rate of 7,500 BOEPD. Future development will take place in several stages and will involve the installation of more production platforms and the drilling of at least 30 wells. Eni (65%) is the operator with partners New Age (25%), and Société Nationale des Pétroles du Congo (10%). The well's primary target is the Bunian structure: a four-way, fault-bounded anticline, which was defined by a 3D seismic survey. It will be drilled to a total depth of 1682 m.
Africa (Sub-Sahara) Eni discovered gas and condensate in the Nkala Marine prospect offshore Congo. The discovery could hold from 250 MMBOE to 350 million MMBOE in place, the company said. In a production test, the Nkala Marine 1 discovery well in the Marine XII block yielded more than 10 MMcf/D of gas and condensate. Eni is the operator with a 65% interest in the block. The remaining shares are held by New Age (25%) and Societé Nationale des Pétroles du Congo (SNPC) (10%). Sonangol and Total will break ground on a deepwater oil pumping project that will increase Angola's production by more than 30,000 B/D.
Latin America-Caribbean Petrobras and CNPC have signed a memorandum of understanding in Beijing to begin negotiations on a strategic partnership, Petrobras has reported. The companies agreed in the document to jointly evaluate opportunities in Brazil and abroad in key areas of mutual interest. Petrobras, the Brazilian national oil company, said in a news release on its website that partnerships will represent an important strategy in its 2017–2021 business plan because of the potential benefits of risk sharing, increasing investment capacity, technological exchange, and strengthening corporate governance. YPF, Total, Wintershall, and BP have announced a USD 1.15-billion joint investment to increase shale gas production in Argentina. The provincial government in Neuquén, where the resource-rich Vaca Muerta Shale is located, has agreed to split the Aguada Pichana area into two parts and combine it with the Aguada de Castro area.
Loss of circulation is a major source of non-productive time (NPT) in the drilling operations worldwide. Different types of loss circulation materials (LCM) have been developed and used to minimize mud losses and mitigate the associated problems. Before a new type of LCM is deployed in the field, it needs to go under extensive laboratory testing with simulated downhole conditions to measure its performance. Therefore, a number of LCM testing methods have been introduced to test the effectiveness of those materials with the ability to have a high-temperature high-pressure (HTHP) environment.
Review of published information indicates different research studies with emphasis on various critical factors to come up with different testing methods and apparatus to evaluate the performance of LCM's under a set of experimental conditions. Some testing methods have the capability of doing the testing at high temperature and/or high pressure while others are built of transparent materials and have the advantage of allowing the researcher to monitor and visualize the invasion depth, fluid level drop, deposited thickness, plugging mechanism…etc. In addition, depending on the size of the apparatus and simulated openings, which frequently are slotted disks, each apparatus has a maximum limit in terms of the particle size of LCM it can handle. Practical considerations should be taken into account when designing a testing cell such as the size of the cell, simplicity and portability, data acquisition system, etc. Large testing cells require large quantities of LCM pills mixed with drilling fluids and, therefore, requiring to mix large quantities of drilling fluids for each test run. Hence, this test should be conducted for selective studies of LCM performance. Cleaning of the test apparatus after each test is an important factor as well to be considered in the design to make it more user-friendly and avoid any detrimental impact on subsequent test results.
The scope of this paper is to highlight, through the analysis of the technologies used and the specific knowledge of the operational team, that the combination of technologies and know-how of the operative people are the key factors for success in well operations.
Description of the different technologies applied during the development of an off-shore field in conventional water as adjustable well head, temporary P&A with mechanical bridge plug, LWD strategy and implementation of the design and procedure developed by the operative team during the activities, based on the real feedback, as light vs high casing profile, 21 ¼″ instead of 29 ½″ diverter using CP 20″ vs 30″, 4 ½″ mono-bore completion for horizontal wells, CT mill motor 2 7/8″, Plug&Perf® methodology, fracture operations material and methodology.
Application of these technologies and knowledge of the integrated team gave a sensible reduction of operative time (40% for vertical wells and 50% horizontal wells in comparison to the initial development well drilled) and relevant cost. The paper will analyze the evolution of the drilling and completion programs and the technologies applied in order to improve efficiency in operating time with reduction in drilling and completion cost. The main topics that will be presented are: Light casing profile (13 3/8″ – 9 5/8″ – 7″ – 4 ½″) vs Heavy (20″- 13 3/8″ – 9 5/8″- 7″- 4 ½″) 20″ CP drilled vs 30″ CP hammered 9 5/8″ casing middle alt depth vs 9 5/8″ below bottom salt Optimized LWD strategy - wire line only as back-up CP hammering (WHP4) - off line hammering in parallel with other operation with JU CP 20″ vs 30″ - smaller hole and material stock optimization (WHP3) 21 ¼″ instead of 29 ½″ diverter (WHP3) OBS II adjustable well head for 9 5/8″ casing (WHP3) P&A with Bridge Plug (Archer plug) instead of cement plug (WHP3) for temporary abandonment Use 4 ½″ mono-bore completion for horizontal wells Bigger CT mill motor 2 7/8″ on 1 ¾″ coil tubing. Plug&Perf® methodology used for selective fracture operations.
Light casing profile (13 3/8″ – 9 5/8″ – 7″ – 4 ½″) vs Heavy (20″- 13 3/8″ – 9 5/8″- 7″- 4 ½″)
20″ CP drilled vs 30″ CP hammered
9 5/8″ casing middle alt depth vs 9 5/8″ below bottom salt
Optimized LWD strategy - wire line only as back-up
CP hammering (WHP4) - off line hammering in parallel with other operation with JU
CP 20″ vs 30″ - smaller hole and material stock optimization (WHP3)
21 ¼″ instead of 29 ½″ diverter (WHP3)
OBS II adjustable well head for 9 5/8″ casing (WHP3)
P&A with Bridge Plug (Archer plug) instead of cement plug (WHP3) for temporary abandonment
Use 4 ½″ mono-bore completion for horizontal wells
Bigger CT mill motor 2 7/8″ on 1 ¾″ coil tubing.
Plug&Perf® methodology used for selective fracture operations.
The paper gives a real experience on how a combination of technology and human experience of the integrated team gives excellent results on learning curve with good impact on Operating Time and relevant cost associated.
The 200,000-B/D Egina FPSO is now on location off Nigeria and is preparing for startup by yearend. Despite a trend toward renewables and low-carbon energy production among European majors, Total remains wholeheartedly committed to deepwater production. The French company expects its deepwater output to reach 500,000 BOE/D by 2020 on the back of its operations in Africa, Brazil, and the US Gulf of Mexico. This will generate cash flow from operations of more than $30/BOE at oil prices of $60/bbl, said Arnaud Breuillac, Total president of exploration and production, during an investor presentation this week. From Africa alone, Total expects to produce 200,000 BOE/D by 2020 and 400,000 BOE/D within the next 5 years, bolstered by three projects: Moho Nord off Congo, Kaombo off Angola, and Egina off Nigeria.