Your web browser is out of date. Update your browser for more security,
speed and the best experience on this site.
You have successfully subscribed to the newsletter!
06 13, 2014 by Fortune
The oil giant is spending billions to tap new oil fields in deepwater far offshore. Take an up-close look at how it’s done.
“You saw Jack? What was it like?”
Jason Morehouse, 35, is wearing navy-blue coveralls. Around six feet tall, he has a buzzcut under his hardhat and a thick goatee that extends about two inches below his chin. At the moment he’s giving me a tour of Tahiti—not the Polynesian island, but a $2.7 billion Chevron oil production platform about 190 miles south of New Orleans. Tahiti sits in more than 4,000 feet of water and is a modern marvel of engineering. When it began producing oil in 2009, it was a pretty big deal for the company. Still is, in fact. Jack, however, is gargantuan.
“I haven’t been out there,” says Morehouse, who is clearly pumped about Tahiti’s younger and much bigger sibling. “I’d really like to get a look at it.”
Morehouse is the operations supervisor on Tahiti, which means he’s in charge of making sure that the floating industrial complex efficiently and safely produces some 34,000 barrels of oil and 14 million cubic feet of natural gas per day. It’s a serious responsibility—and one he embraces with gusto. (“I gotta warn you,” he says, “I get pretty excited about all of this stuff,” before launching into an inspired discourse about high-pressure and low-pressure separator tanks.)
When I ask him if he’d like his next assignment to be on Jack, he displays admirable loyalty to his own floating home. “Being on Tahiti is just as exciting,” says Morehouse. “Some of what they’re doing at Jack is more advanced, and some of what we’re doing is more cutting-edge.”
It’s a perfectly rational and diplomatic answer. But I hear it there—a tinge of envy in his voice.
After all, the Jack/St. Malo (to give its full name) platform is the newest, biggest thing going for Chevron, No. 3 on this year’s Fortune 500 list, with $220 billion in revenues, in the Gulf of Mexico. In fact, it’s the largest structure of its kind in the Gulf, period. The $7.5 billion floating production facility has a displacement of 160,000 metric tons and is designed to process oil and gas drawn from wells in two separate fields—Jack and St. Malo—that are as deep as 29,000 feet below sea level. Utilizing some 480,000 total feet of pipe, the platform will be able to process up to 177,000 barrels per day of hydrocarbons. (In the oil industry the term “platform” is used for structures that pull and process oil from wells, whereas a “rig” is used for those that drill.) Jack/St. Malo sits in 7,000 feet of water, and is located roughly 90 miles south of Tahiti—significantly farther out into the Gulf. It’s the frontier.
Jack is also symbolic of the big bet that the company is making in the Gulf of Mexico on production in deepwater—defined by Chevron CVX 0.31% as more than 1,000 feet—as a growth driver for years to come. In addition to Jack, which should begin producing oil by the end of 2014, Chevron is prepping a slightly smaller cousin, a $5.1 billion platform called Big Foot, to begin production in 2015. It also has a 42.9% stake in Hess’s HES 0.00% $2.3 billion Tubular Bells deepwater development, which should start producing oil this year. The model for major oil and gas projects is typically for one company with a majority stake to take the lead, but to share the investment costs with two or three of its peers. For instance, Chevron holds a 50% stake in the Jack field and 51% of the St. Malo reservoir, with stakeholders such as Petrobras of Brazil and Norway’s Statoil sharing in the projects.
To be sure, the Gulf of Mexico is hardly the only offshore area where Chevron is investing heavily. It operates in deepwater off the west coast of Africa and in Brazil, for instance. And its biggest capital investments by far are in a pair of projects off the northwestern coast of Australia. The cost of its Gorgon liquefied natural gas mega-project, originally budgeted at $37 billion and scheduled to begin producing gas in 2015, has risen to $54 billion. (Chevron is the lead developer, with a 47.3% stake, and is sharing the investment with Exxon Mobil XOM 0.57% and Shell, among others.) The nearby Wheatstone LNG development has a price tag of $29 billion and will begin producing gas in 2016.
Those two projects are crucial to Chevron’s future. But developing previously unreachable portions of the Gulf of Mexico not only gives the company a way to replace declining reserves elsewhere but also serves as a way to hone techniques it can export to other parts of the world. “Chevron has specifically identified deepwater as one of its key technological areas of expertise,” says Pavel Molchanov, an oil industry analyst with Raymond James.
Chevron’s big push into deeper water in the Gulf is also emblematic of a broader comeback for oil and gas development in the region after BP’s horrific Deepwater Horizon accident in April 2010, in which an explosion killed 11 workers and led to one of the largest oil spills in history. A government-imposed drilling moratorium afterward had a chilling effect on production in the Gulf of Mexico. But investment is on the rise and the Gulf is set to surge.
The unexpected boom in onshore oil and gas production driven by development of shale-drilling techniques has deservedly dominated the energy story in the U.S. over the past several years. However, deepwater production in the Gulf may be poised to grow at a faster rate going forward. According to analyst Molchanov of Raymond James, onshore production in the U.S. grew at an annual rate of 4.7% for the five years through 2012, while production in the Gulf of Mexico actually shrank during the same period. But Molchanov estimates that from 2012 to 2020, offshore production in the Gulf, mainly from deepwater, will grow 8.3% per year, vs. 6.1% for onshore oil and gas. And Chevron will be one of the biggest beneficiaries. “Chevron could easily double production [in the Gulf] by 2020,” says Molchanov.
To learn more about how the oil major is making this push, I recently took a trip down to the Gulf for an up-close look. My first stop was the Kiewit shipyard in Ingleside, Texas, where Chevron’s Big Foot platform was in the process of being assembled and tested, and where Jack was housed for final fabrication before it was towed out and put in position in the Gulf recently to begin the monthslong process of readying it for production.
As I drove over the causeway from Corpus Christi to Ingleside on a cloudy Tuesday morning, I could see Big Foot’s gargantuan profile across the bay. It was the largest structure in view. Turns out, it’s even more awe-inspiringly large when you get near it. The platform is some 500 feet from the top of its flare boom to the bottom of its four-legged hull, and houses an onboard power plant that could support a small city. Sitting in the water, it’s roughly the height of a 30-story building, and each deck has the dimensions of a football field. The hull was built in Korea and arrived in Ingleside in March 2013 after a two-month sea voyage. But that was just the beginning of the assembly process.
Jan 14, 2021 | LMOGA
Dec 02, 2020 | LMOGA
Nov 18, 2020 | LMOGA
Nov 07, 2020 | LMOGA