We generated adjusted EBITDA of $2.6 billion and DCF attributable to the partners of Energy Transfer, as adjusted, of $1.3 billion.
Our excess cash flow after distributions was approximately $900 million.
On an incurred basis, we had excess DCF of approximately $540 million after distributions of $414 million and growth capital of approximately $360 million.
As a reminder, we expect the combined company to generate more than $100 million of annual run rate cost synergies, and this is before potential commercial synergies.
In early June, we commenced service to provide transportation for approximately 65,000 barrels per day of crude oil from our Cushing terminal to our Nederland terminal, providing access for Powder River and DJ Basin barrels to our Nederland terminal being an upstream connection with our White Cliffs Pipeline.
And as we mentioned on our last call, we are moving forward with Phase 2, which will increase the capacity to 120,000 barrels per day.
Phase 2 is expected to be in service early in the second quarter of 2022 and is underpinned by third-party commitments.
We have commissioned the next significant phase of the Mariner East project, which brings our current capacity on the Mariner East pipeline system to approximately 260,000 barrels per day.
Year-to-date, NGL volumes through the Mariner East pipeline system and Marcus Hook terminal are up 12% over the same period in 2020.
As a reminder, with the completion of the remaining expansions of our LPG facilities at Nederland, earlier this year, we are now capable of exporting more than 700,000 barrels per day of NGLs from our Nederland terminal.
And when combined with our export capabilities from our Marcus Hook terminal, as well as our Mariner West pipeline, which exports ethane to Canada, our total NGL export capacity is over 1.1 million barrels per day, which is among the largest in the world.
Year-to-date through September, we have loaded more than 16 million barrels of ethane out of this facility.
And in total, our percentage of worldwide NGL exports has doubled over the last 18 months to nearly 20%, which was more than any other company or country for the third quarter of 2021.
At Mont Belvieu, we recently brought on a 3 million-barrel high-rate storage well, which takes our NGL storage capabilities at Mont Belvieu to 53 million barrels.
This project allows us to move approximately 115,000 Mcf per day of rich gas out of the Midland Basin and to operate existing capacity more efficiently while also providing access to additional takeaway options.
In addition, it can easily be expanded to 200,000 Mcf per day when needed.
In September, we entered into a 15-year power purchase agreement with SB Energy for 120 megawatts of solar power from its Eiffel Solar project in Northeast Texas.
Consolidated adjusted EBITDA was $2.6 billion, compared to $2.9 billion for the third quarter of 2020.
DCF attributable to the partners as adjusted was $1.31 billion for the third quarter, compared to $1.69 billion for the third quarter of 2020.
While we saw higher volumes across the majority of our segments, including record volumes in the NGL and refined products segment, these benefits do not offset the significant optimization gains in the third quarter of 2020 related to our various optimization groups, as well as the onetime $103 million gain in our midstream segment.
On October 26, we announced a quarterly cash distribution of $0.1525 per common unit or $0.61 on an annualized basis.
Adjusted EBITDA was $706 million, compared to $762 million for the same period last year.
Higher terminal services and transportation margins related to the increased throughput on our Nederland and Mariner East pipelines in the third quarter of 2021 were offset by a $55 million decrease in our optimization businesses at Mont Belvieu and in the Northeast, as well as increased opex and G&A.
NGL transportation volumes on our wholly owned and joint venture pipelines increased to a record 1.8 million barrels per day, compared to 1.5 million barrels per day for the same period last year.
And our fractionators also reached a new record for the quarter with an average fractionated volumes of 884,000 barrels per day, compared to 877,000 barrels per day for the third quarter of 2020.
For our crude oil segment, adjusted EBITDA was $496 million, compared to $631 million for the same period last year.
The improved performance on our Bakken and Bayou Bridge pipelines as a result of recovering volumes in the third quarter of 2021 did not offset approximately $100 million of onetime items in the third quarter of 2020.
In addition, we had approximately $20 million in other optimization reductions, as well as increased opex and G&A expense year-over-year.
For midstream, adjusted EBITDA was $556 million, compared to $530 million for the third quarter of 2020.
This was largely the result of a $156 million increase related to favorable NGL and natural gas prices, as well as volume growth in the Permian and the ramp-up of recently completed assets in the Northeast, which were partially offset by a decrease of $103 million due to the restructuring and assignment of certain contracts in the Ark-La-Tex region in the third quarter of 2020.
Gathered gas volumes were 13 million MMBtus per day, compared to 12.9 million MMBtus per day for the same period last year due to higher volumes in the Permian, Ark-La-Tex and South Texas regions.
In our Interstate segment, adjusted EBITDA was $334 million, compared to $425 million for the third quarter of 2020 primarily due to contract expirations at the end of 2020 on Tiger and FEP, as well as a shipper bankruptcy on Tiger and lower demand on Panhandle and Trunkline partially offset by an increase in transported volumes on Rover due to more favorable market conditions.
And for our intrastate segment, adjusted EBITDA was $172 million, compared to $203 million in the third quarter of last year.
Our full year 2021 adjusted EBITDA remains $12.9 billion to $13.3 billion.
And moving to a growth capital update, for the nine months ended September 30, 2021, Energy Transfer spent $1.08 billion on organic growth projects, primarily in the NGL refined products segment, excluding SUN and USA Compression capex.
For full year 2021, we continue to expect growth capital expenditures to be approximately $1.6 billion, primarily in the NGL refined products, midstream, and crude oil segment.
After 2022 and 2023, we continue to expect to spend approximately $500 million to $700 million per year.
As of September 30, 2021, total available liquidity under our revolving credit facilities was approximately $5.4 billion, and our leverage ratio was 3.15 times per the credit facility.
During the third quarter, we utilized cash from operations to reduce our outstanding debt by approximately $800 million.
And year-to-date, we have reduced our long-term debt by approximately $6 billion.

Summary:
Our full year 2021 adjusted EBITDA remains $12.9 billion to $13.3 billion.