What's new in production

	Vol. 229 No. 1
VICTOR SCHMIDT, DRILLING ENGINEERING EDITOR, schmidtv@worldoil.com

Deepwater production research. The industry continues to move into deeper waters both for drilling and production. However, we can now drill in deeper waters than we can produce from, because of the technical challenges and high costs of producing from deeper water. New techniques and production equipment continue to come onto the market, but advances are slow and the industry is cautious in applying new technology. There are still problems to be addressed that require research.

Chevron has recognized the need and stepped up to the challenge in a new partnership with the Massachusetts Institute of Technology (MIT). Together they have established the Chevron-MIT University Partnership program under the MIT Energy Initiative. Chevron has underwritten new research with a five-year, $5 million program for remote and ultra-deepwater development and production research, as well as two fellowships. The program’s goal is to develop technologies to access hydrocarbons in a safe, cost-effective and environmentally friendly manner from waters deeper than 11,400 ft (3,000 m).

Topics to be considered include: long-distance tiebacks; small-field developments; subsea, floating, riser and export system reliability; flow assurance; advanced production systems; compact modular production systems; seabed pumping; and cost control. The research projects may also consider arctic development issues.

The program’s longer-term vision includes tying multiple fields together into subsea processing centers that will export hydrocarbons long distances via pipeline. To address the different time frames needed, the program will designate present, near-term and long-term deepwater research needs.

Major themes being considered include; flow metrology (sensors), ROV/AUV standardization, continuous monitoring, seabed environment prediction, stabilized fluids and VIV in risers and pipelines. Chevron’s research specialists will work closely with MIT’s principal investigators to guide the research efforts. Projects will be supported at the “seed” level for one year or at a regular project level for up to three years.

Subsea multiphase pump. BP began transporting production from King Field in the Gulf of Mexico using two subsea pumps. The company says the pumps are set in the deepest water of any subsea pump to date and transport fluid across the farthest distance of any installed thus far. The deepest previous installation was in 3,000 ft of water and pumped production six miles to a host platform.

King Field is in Mississippi Canyon Block 84 in 5,500-ft water depth and the pumps push production 18 mi to the Marlin TLP, which is in Viosca Knoll Block 915 about 75 mi off the Louisiana coast. BP operates the field with 100% interest.

Project. Thailand’s national oil company, PTTEP, is installing Arthit Field’s Central Processing Platform in the Gulf of Thailand. The platform will be secured in 262 ft of water in the Navamindra Petroleum Area, about 350 mi south of Bangkok and 230 km off Songkhia Province’s coast.

The platform is one of the largest offshore structures in the Asia-Pacific region, weighing over 16,750 tons. PTTEP is operator with 80%, while partners Chevron Thailand E&P and Moeco Thailand hold 16% and 4%, respectively.

The system will begin producing from 88 wells in March 2008 and will produce up to 330 MMcfd of natural gas. Arthit North Field will come onstream in September 2008, adding 120 MMcfd. Arthit Field, Bongkot Field, Bongkot North and Bongkot South together are expected to produce up to 1.5 Bcfd next year. Additional new gas production from the Malaysia-Thailand Joint Development Area will begin flowing in 2009.

Rig counts. Everyone is familiar with the Baker Hughes rig count, and probably receives the company’s routine statistical updates. The company has recently enhanced that data set by building a website tool linking its rig data into a geography information system. Using the new tool and simple button selection controls, it is possible to quickly and visually review North American activity by oil/gas, depth, development/exploration, location and trajectory, as well as assorted culture overlay options. From the company’s home page, click on Interactive Rig Count Maps under the Highlights section.

New output. Petrobras brought two platforms online, P-52 and P-54. The P-52 semisubmersible began producing 20,000 bpd of 28°API oil in late November from 18 wells in Roncador Field in the Campos Basin offshore Brazil. Production is expected to grow to the system’s limit of 180,000 bopd and 265 MMcfd of natural gas by summer 2008. The platform is in 5,900 ft of water and 77 mi offshore.

In early December, the P-54 also began production. The vessel is an FPSO converted from the ship, Barão de Mauá, and is designed to produce 180,000 bopd from 11 wells. Gas flow is expected to reach 63.5 MMcfd, which will be transported to the coast by pipeline. The FPSO can compress 212 MMcfd of gas and store up to 2 million bbl of oil.

BHP Billiton started producing from the Stybarrow Field offshore northwestern Australia. The nine-well subsea development is tied to an FPSO that can handle about 80,000 bpd of oil. The field is in 2,706 ft of water in Block WA-32-L of the Exmouth sub-basin.

BP began flowing natural gas from Mango Field offshore Trinidad. The field is 35 mi from Galeota Point, in 235 ft of water in the South East Galeota Block. It is producing from an unmanned platform to supply up to 750 MMcfd of gas plus associated condensate to the Atlantic liquefaction plant for domestic markets and LNG export.

BPZ Energy started oil production from Corvina Field offshore northwestern Peru in Block Z-1. The CX11 platform stabilized production at 2,500 bpd of oil. The field will produce from two wells, 21-XD and 14D.

Melrose Resources began producing from the West Dikirnis-2 well in West Dikirnis Field, onshore in Egypt’s Nile Delta. Output will reach a 10,000 bopd in early 2008.

Total started production from Sisi-Nubi Fields offshore Kalimantan in Indonesia. The fields are in 196-295 ft of water about 15 mi off the Mahakam Delta in Mahakam and Tengah Blocks. Over the next 18 months, the 27-well development program will bring 350 MMcfd to market. Total is operator at 47.9% interest with partners Inpex at 47.9% and Pertamina at 4.2%.