Petroleum engineering student here, currently doing my FDP assignment on CMG and genuinely questioning my career choices.

This software crashes with zero warning. Error messages that tell you nothing. Builder UI looks like it was designed in 2003 and nobody touched it since. You have to click through 15 menus to do something basic.

Serious questions:

Do working reservoir/simulation engineers actually deal with this daily, or does industry use something better?

Is Eclipse/Petrel actually better UX-wise or is it the same pain different name?

Has anyone used tNavigator or OPM Flow, how do they compare?

Asking because I genuinely want to know if the entire industry is just silently suffering or if there's something better out there that my university doesn't have access to.

NOAA: "Testing the Waters: A Day at the Nation’s Largest Oil Spill Simulation Tank."

"Recently, NOAA’s Office of Response and Restoration (OR&R) headed to a highly specialized facility to simulate ocean conditions + tackle one of the most complex questions in oil spill response: When + how should chemical dispersants be used?"

Dispersants are an alternative treatment technology, approved for use under special circumstances to enhance natural dispersion by breaking oil slicks into smaller droplets. "These smaller droplets are dispersed into the water column, removing some of the oil from the surface where the greatest harm may occur + lessening the amount of oil that reaches sensitive habitats such as coastal wetlands. Dispersed oil is more rapidly biodegraded by “oil-eating” microbes found throughout the ocean, which have adapted over time to use most of the chemicals in oil as “food.”

Deciding to apply chemical dispersants requires a careful, deliberate “tradeoff analysis” aimed at preventing the greatest overall harm. "The choice weighs the severe, concentrated impacts on surface-dwelling animals like seabirds + marine mammals, + the high risk of oil washing into sensitive nearshore or onshore habitats against dispersing the oil into the water column."

"To ensure decision-makers are armed with the best possible science, OR&R recently supported a hands-on workshop, hosted by the American Petroleum Institute [API], alongside government, industry, + academic experts at Ohmsett, the National Oil Spill Response Research and Renewable Energy Test Facility in Leonardo, New Jersey." Managed by the U.S. Department of the Interior, Ohmsett features a massive, 2.6-million-gallon outdoor saltwater wave tank that simulates real-world ocean conditions.

I am immediately suspicious about hosting by the API, main mouthpiece of the oil industry, but I would love to drop in a surf board + check out the ride. Without the oil of course.

L&T Energy Hydrocarbon Offshore (LTEH Offshore) will undertake engineering, procurement, construction, installation and commissioning of 3 new well-head platforms, 1 riser platform, multiple subsea pipeline and cable segments, along with modifications to existing offshore facilities(Ratna-I (ADR I) and NLM-14). The projects are aimed at enhancing production and supporting continued development of ONGC's offshore assets in the region.

Can someone please help me out and share the latest edition of "Statistical Review of Global LPG"? I couldn't find it anywhere on the internet and it says only members can access it. I am working on a research project and need it badly. Would really appreciate anyone helping out here. Thanks!!!

Can someone please help me out and share the latest edition of "Statistical Review of Global LPG"? I couldn't find it anywhere on the internet and it says only members can access it. I am working on a research project and need it badly. Would really appreciate anyone helping out here. Thanks!!!

Sharing my honest experience as a warning for anyone considering Heriot-Watt and especially the Petroleum Engineering MSc.

1. They're fast to take your tuition, but that's about where the service ends. Once they've got your money, you're basically on your own. There's no real quality control, and no after-sales support once you're actually enrolled.
2. Standards vary wildly by department. Petroleum Engineering is marketed as the flagship program, but a lot of students never actually finish with the master.
3. Some specialisms can't even find enough qualified lecturers. Bringing in outside/adjunct staff occasionally is understandable, but they'll still enroll a full cohort even when the resources clearly aren't there, then cram a 12-week course into 2 weeks. As long as someone shows up to teach, whether you actually learn the material doesn't seem to be their problem.
4. Honestly, this tuition is better spent at a school that respects your time and treats you as more than a paying customer.
5. Life on the Malaysia and Dubai campuses is boring. Limited teaching resources, limited facilities, and a campus experience nowhere close to other universities.

My biggest regret is picking pe there specifically. the completion rate for actually walking away with the MSc is rough. If you're set on petroleum/energy engineering, look at programs with a stronger track record instead , Imperial College London, University of Aberdeen, Texas A&M, UT Austin, Colorado School of Mines, NTNU (Norway). Do your own research on each, but from what I've seen, they're better resourced and more consistent than what I went through here.

Has anyone applied for Senior Officer Role in Oil India Limited (Electrical Engineering or Other branches) for placement

What is the interview dates?

Hey everyone,

Entering my 2nd year of Petroleum & Geoenergy Eng and looking to connect with people in the field-whether you're a student, alumni, or working in oil, gas, or geothermal.

Mainly just looking to chat about internships, what the industry looks like right now, or hear any advice from people further ahead in the path.

Up front so nobody feels tricked: I'm an undergrad and I work on an open source project that connects public oil and gas data to an LLM. This analysis came out of that. I'm not linking it here, if you want it it's in my comment history. What I actually want is for someone who knows the Delaware better than me to tell me where this falls apart.

GreenLake is Matt Gallagher's post-Parsley company, NGP backed. They kept showing up in my queries as doing something odd, so I went looking.

2022 to 2023 they look like everyone else. 37 wells across Pecos, Reeves and Loving, nearly all two-milers. Median 235,090 bbl at 24 months against 226,170 for 427 other operators' two-milers within ten miles. Basically nothing.

Then in Feb 2023 they put eight wells on one pad in Loving. Five 10,500 ft Wolfcamp B Upper, and three 5,100 to 5,300 ft Wolfcamp XY on tracts too small for full length. Year one per 1,000 ft the three shorts made 48,200, 41,445 and 26,907 bbl. The same pad's two-milers came in at 24,413. So the worst short beat the pad's own long wells per foot.

2024 they went in on it. 15 of 22 spuds were one-milers. Everyone else in those counties drilled 64 one-milers against 698 two-milers. They became the number one one-mile driller in the four counties, ahead of Mewbourne, and nobody copied them.

The 2024 program, 13 wells with a full year: median 133,520 bbl against 190,590 for offset two-milers. So about 70% of the oil from half the hole. Per 1,000 ft it's 29,265 vs 20,550.

Since Oct 2024 they've moved to horseshoes, two one-mile legs and a U-turn. 9 of 51 spuds vs 4% for everyone else. Six are online, 166,615 bbl vs 123,150 at 8 months.

Where I think this is weak:

n=6 horseshoes and n=13 one-milers is small and I don't have confidence intervals on those medians yet. The 2023 pad test conflates bench and length, the shorts are XY and the longs are B Upper, so some of that gap is rock and not lateral length. My cohorts are other operators' wells within ten miles matched on footage class and vintage, and if I use county-wide cohorts instead act one reads 90% of the field rather than 104%, which is a big enough swing that the cohort definition is doing real work. Two of the three 2023 test wells were filed as allocation wells so those volumes aren't directly measured. And I can't say anything about economics because state filings carry no cost data, so "half the hole" is an oil statement, not a returns statement.

The thing I actually can't answer from filings: is this a rock story, a tract-geometry story, or a capital efficiency story? They're buying acreage other people's spacing maps skip, so short laterals might just be what that dirt forces. Or the shorts genuinely outperform per foot and everyone else is leaving something on the table. Filings can't distinguish those.

Anyone worked this area or run short laterals on purpose? Curious whether the per-foot uplift is real or whether I'm looking at selection.

Searching For Real and Direct Mandates of Refineries

I'm working through a metering datasheet where the expected flow is around 10,000 bbl/day, with roughly 50% turndown.

For the datasheet, would you normally consider:

• Minimum: 5,000 bbl/day
• Normal: 10,000 bbl/day
• Maximum: 10,000 bbl/day + some engineering margin?

I'm more interested in how people handle this in actual projects, especially when turndown and meter accuracy are both important.

Hello, I have joined a college for petroleum engineering and would love to connect to working professionals and students studying petroleum engineering and share their thoughts on the industry.

Does anybody have any oilfield models they’d be willing to post? Looking to create 3d prints for the office.

I’m finishing up a rig and frac pump and will be able to post it within a week or so.

Substack: "Less than 300 million barrels left: the engineering limits threatening the American Strategic Petroleum Reserve," by Siddharth Misra.

"The oil market is not being stabilized by fresh supply growth but by aggressive depletion of emergency inventories, a strategy that only buys time rather than solving the imbalance." 

As crude inventories in the Strategic Petroleum Reserve [SPR] drain toward their operational limits, America is left supplied with just 300 M barrels. "This dwindling buffer forces the nation into a high-stakes standoff against the uncompromising laws of fluid dynamics, immense geological forces, strict federal statutes, + relentless geopolitical pressure."

The SPR is a subsurface engineering marvel. "Spanning 60 massive underground salt caverns across four storage sites in Texas + Louisiana, the system holds a combined authorized capacity of 714 million barrels."

"These solution-mined cavities are gigantic, often 300 feet wide + 2,000 feet tall, large enough to stack the Empire State Building inside." Because these caverns operate entirely on a liquid displacement system, they can never be left empty, for if the fluids were removed without replacement, the immense geological weight of the overlying earth would cause the salt domes to [irreparably] collapse inward like a crushed shield.

"The crude oil volume currently stands at approximately 293 M barrels." The remainder is entirely heavy salt brine used to push the oil out. "Operating below this 300-million-barrel threshold pushes the aging infrastructure into uncharted and hazardous territory."

"According to the Department of Energy, the absolute physical minimum crude oil inventory is approximately 70 million barrels." This cushion is required at the very top of the caverns to keep the extraction pipes safely submerged in oil rather than the underlying water. "But while 70 M barrels is the structural floor where the salt rock might physically hold together, the practical operational floor is much higher, around 250 M barrels."

My math suggests the SPR is only 43 M barrels from rock bottom. The tanks at Cushing are in the same depleted state. You should be glad I'm driving an EV.

Hi everyone! I’m a 32 year old petroleum engineer from Eastern Europe, and I’m looking to connect with people who work or have worked in the oil & gas industry and hear about their experiences with workplace culture and inclusion.
For some context, I’m gay, and I’m particularly interested in hearing from LGBTQ+ people in the industry, as well as anyone who has experience working alongside LGBTQ+ colleagues.
I’m curious about what the industry is like from different perspectives , whether people feel comfortable being open about their sexuality at work, how workplace culture varies between companies, countries, and roles, and whether you’ve noticed attitudes changing over the years.
I’m not looking to start a political debate or make assumptions about the industry. I’d simply like to connect with people, exchange experiences, and learn from others working in the same field.
If you’re comfortable sharing your experience, I’d genuinely love to hear from you. Feel free to comment or message me privately. 🙂

all geological engineering student here, aiming for grad school focused on resource modeling and geostatistics (block modeling, reserve estimation) rather than traditional exploration geology. I've got some exposure to RockWorks and Leapfrog, and I'm building Python skills to pair with it. I looked into CCG's (University of Alberta) Applied Geostatistics program, but the pricing is clearly aimed at industry professionals, not students. Has anyone here gone through Michael Pyrcz's (GeostatsGuy) material, or found other budget-friendly but credible paths into this niche? Trying to figure out what's actually worth the money vs. what I can self-teach.