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Tag Archives: human resources professionals
3 Reasons Hiring In a Pinch Hurts Your Business
Balance your efforts to both fill the position and get quality candidates
Entrepreneurs and hiring managers, take your time and find the right candidates. Here's how.
By Karima Mariama-Arthur, Esq.
From the Mouths of Hiring Managers: The Real Deal on Getting the Gig
Learn more about the process in order to master your strategy
Hiring managers share the inside scoop on the applications process and how they choose the…
By Janell Hazelwood
August 29, 2013 Tags: Employment, human resources professionals, job search, recruitment

subset: commoncrawl


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Plymouth University - MetNet
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Intensive English programs
English at an Intensive English Centre (IEC)
NSW government schools offer intensive English programs for students who need to improve their English.
Teaching takes place in a government school
The course introduces students to the Australian school system and provides intensive English language tuition, orientation and welfare support. This helps students adjust to their studies quickly.
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Students generally study an intensive English program for approximately 20 weeks which includes a transition program that helps them successfully integrate into studies at their chosen secondary high school.
Students learn English through the key learning areas, including Maths, Science, History and Geography.
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University-trained and fully qualified English as a Second Language (ESL) teachers provide lessons in English for key secondary high school subjects.
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Are there any minimum requirements?
You need to be at least 12 years of age to enrol in an IEC.
Your school reports must indicate you have studied English in your home country and achieved good grades in all subjects.
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Our Intensive English Centres have four intakes a year, at the beginning of each school term.
View a calendar of term dates.
Where are the Intensive English Centres (IEC) located?
There are 14 Intensive English Centres located in selected NSW Government Schools throughout Sydney and Wollongong. There is also the Cleveland Street Intensive English High School in Sydney. Normally you are placed in the IEC closest to the school you have chosen for your studies.
Locate an Intensive English Centre on a map.
How to apply
To apply to study at an Intensive English Centre, complete Part 7 of your International students application.
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Search for NSW government primary and high schools available for enrolment by international students or temporary residents:Find out more about studying at a NSW government school
Intensive English programs
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Intensive English programs
ESOS Framework
The Australian Government wants international students to have a safe, enjoyable and rewarding study experience in Australia.
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After the party it's the hotel lobby...
... but that comes a wee bit later because we first need to meet the monster princess that is pregnant and her protectors. She is on the run because some other monsters don't want this baby to be born… yeah I don't know why either. While on the run the protectors lose the princess and apparently meet the nerdy guy. The girl protector keeps talking about how he smells and you wonder if that means she plans to eat him. Luckily, maybe, for him he has a ...
Our last day in Hong Kong
... way but the all over experience and I learnt so much!! When my parents were here in Hong Kong one of their friends was a Chinese born English, Chinese studies Professor and after not receiving a Christmas card from this year, dad was determined to track her down and see if she was ok. And at 93 she was still kicking and so on the ball that she surpassed dad when she remembered the little ...
Fun with an oceanic theme
... It turned out to be really good!!! They had loads of different shows and feedings but there was only one I was interested in- yep you guessed it.... The dolphins show. We missed the beginning but it was the sea lion part. Paul said it was nothing on the shows in Florida; no hoops in sight. I absolutely loved it but it was the first time I'd seen them like that. Paul managed to win me another teddy, an orange elephant that I really wanted to keep but we have ...
Hong Kong
... holding the lid down. The weather was just beautiful, the sky crystal clear. A big but enjoyable day.
Aberdeen floating village is located at the Aberdeen Harbour in the Southern District of Hong Kong. The harbour contains approximately 600 junks, which house an estimated 6,000 people.
Since the 19th century, Aberdeen has emerged as one of the most important fishing ports in Hong Kong. ...
A Second Day in Hong Kong
... of salespeople. Jo showed polite interest but we managed not to buy anything.
The final stop was the Stanley Market which is world famous for clothes, jewellery, Chinese handicrafts and curios. We had a good look round but did not buy anything (actually we didn't have any money). Stanley Bay nearby is somewhat reminiscent of a seaside resort in the UK with typical English pubs but also Starbucks and MacDonald's situated adjacent to each ...


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Mahmoud Salem: Letter from an Egyption revolutionary
There are 33 comments on the TwinCities story from Sep 20, 2012, titled Mahmoud Salem: Letter from an Egyption revolutionary. In it, TwinCities reports that:
I have a confession to make: While the whole world was transfixed by us, yet again, due to that whole attacking-the-embassy business, I was going through a tumultuous emotional journey, alternating between bewilderment, horror and shock-based laughter, ending with the most unexpected of feelings: pride.
Join the discussion below, or Read more at TwinCities.
Manchester, UK
#1 Sep 21, 2012
I have one hell of a lot of respect for this guy ;) you may know him better as Sandmonkey :)
Did anyone read this?
"I am here for a laugh "
Since: Mar 12
Location hidden
#2 Sep 21, 2012
I know these guys , a group of selfish communists with no self respect or regard for their own country , the only place these clowns deserve to be is jail .
These cowards have caused a lot of instability in Cairo and now after they understood that no one longer supports their crap they resorted to violence and riots.
Since: Jan 12
Location hidden
#3 Sep 21, 2012
disagree with you, not every revolution guy is communist or secularist..... man u seem like a hater of our revolution lol
Instability is something expected, the french people remained 3 years into revolts untill they succeeded to build great france and took france for advanced era
Manchester, UK
#4 Sep 21, 2012
Rubbish, they had a vision of Egypt for EVERYONE but unfortunately there were too many 'little men'. They were not organised enough for the likes of the Muslim Brothers or SCAF :(
They have 4 years to get their act together and I for one will be cheering them on ;)
BTW if it wasn't for guys like this there would of been no regime change and the people would still be stuck with Mubarak :(
Manchester, UK
#5 Sep 21, 2012
nothing wrong with being secularist EL :D I agree with you though
Courbevoie, France
#6 Sep 21, 2012
Dear Mahmoud Salem,
I have a confession to make : while the people who gathered in Tahrir square 25th January - 11 February 2011 did represent almost all specturm of the Egyptian society, yet MOST of the gatherings took place later (a decent vocabualry for mobs-demenostrating)were driven by selfish objectives (a decent vocabulary for domestic/external conspiracies), and that does include the brotherhood group, the facebook kids (you and your fellows ?), so called Human Rights Organization in Egypt (a decent vocabulary for USAIDS bribes receivers),
When Mr. Barak Obama made his wonderful statement : "We must educate our children to become like the young Egyptian people" , it was 'accurately designed' for the mentality of Egyptian kids to control(you and your fellows) them by remote control, well adjusted to fit their ego (suddenly they became a 'somebody' of have been being nobody ), and from there the CIA -for a while- had a window to dirve some gatherings (...) which had to stop and the cells so called Human Rights Organizations/Activists were exposed by the Egyptian Intelligence.
The history, has always been the judge, and it will always be. While the great revolution of France did eventually achieve the historical great results we know, yet the history has recognized that it gained its dynamics from MOBS, nobodys-who-were-deceived-of-b eing-somebody, and of course genuine French people as well (similar to those Egyptians who filled the streets of Egypt between 25 Jan-11 Eeb 2011),
The image of street kids throwing stones and burning La Institute d'Egypte destroying 100s of rare books, will stay in mind for how many domestic groups exploited street kids for many dirty demenostrations took place (activists took part as well),
Finally,, nobody can not become somebody when everybody knows that he does not represent anybody,
Best Regards,
"I am here for a laugh "
Since: Mar 12
Location hidden
#7 Sep 21, 2012
These guys did nothing good for the country , if it was not for the MB the uprising would have failed miserably , its just those kids have been given extra attention from the media during the scaf period which made them antagonistic
Courbevoie, France
#8 Sep 22, 2012
... exactly !!
Manchester, UK
#9 Sep 22, 2012
The MB were not around in the beginning, they were standing back hedging their bets! They lied throughout :( the only reason they were voted in was because the youth groups hadn't got their act together properly. If you were to count the first round of votes MB got something like 21% and SCAF got roughly the same, that concludes that a majority of Egyptians did want neither :)
The second round of voting was like voting the the lesser evil and that's why MB are now in power!
Think Morsi should now do the right thing and release the revolutionaries from prison now, because I'm pretty sure if it was for them in the beginning he would still be sitting in Tora prison :(
We will have to agree to disagree on this one :)
#10 Sep 22, 2012
Egyptians are hero people! They have to defend thier religion in what ever ways...damn with what americans calls "thier value"
Since: Jan 12
Location hidden
#11 Sep 22, 2012
Those kids were the initial guys in streets protesting against mubarak and beat his evil police forces,many died of them as sacrifice to see the country in better case.
While muslim brotherhood were watching the news on first three days on TV, After they saw the success of protest and failure of police, The whole society was in streets by 28th january.
The muslim brotherhood did join the revolution after some days.
Praise 6 april heros and Kafaya movement,those were the ones who invited egyptians to protest against mubarak regime.
As i remember before our revolution by some days, after success of tunisians, Kafaya movement guys went to share joy front of tunsian embassy in cairo with statements against mubarak, even mubarak pictures were burnt.
Most victims of revolts were not muslim brotherhood guys, they were public young egyptians
Since: Jan 12
Location hidden
#12 Sep 22, 2012
Marshal is obviously against the revolution from beginning, Maybe he was one of mubarak guys or a person who gets benefit by mubarak regime.
I have supported the muslim brotherhood before and defended them as well and from time to other, People forgive them. then after mursi became president.....Their hypocrisy became clear for all
Mursi didnt fulfill any promises and his prime minister is hypocrite and big liar,cheater.
The most sad thing: they pretend to be good image of islam religion while they only discredit the islam.
Islam is not cheat....islam is not hypocrisy....islam is not lying and using others.
The muslim brotherhood are really malicious organisation and dangerous on egyptian society.
Abd nasser was right and ok to put them in jails and so Mubarak.
Now, muslim brotherhood are trying to control each inche of the country to be The next dictators after mubarak, Sow why we made a revolution at all then?
Since: Jan 12
Location hidden
#14 Sep 22, 2012
untill todays:
the army officers who went for tahrir with protesters against the scaf and tantawy el harami, are jailed!
what does that mean?? Mursi wasnt that good leader enough to represent the revolution, because muslim brotherhood only do care about themselves, they will not free any army officer or protesters.
Since: Jan 12
Location hidden
#15 Sep 22, 2012
secularism by islamic features are welcomed!
but by western features not welcomed!
thanx for agreeing
Marshal tantawy is supporter of his lovely criminal hero tantawy,the one who killed 67 guys at Mohamed mahmoud street.
tantawy must gain Death penality for killing protesters
Courbevoie, France
#16 Sep 22, 2012
salam Forza,
no, the military did not kill any proterster duriing the 25th Jan - 11 Feb 2011 !!,
if those who for example set fire in the L'Institute d'Egypte and destroyed 100s of rare books, are called protesters, then whom 'mobs' should fit then ?, dealing decisively with incidents where buldings of courts, factories, TV Headquarter, Military premises, government, etc were attacked is a full duty, and it had to be dealt with stongly,
.. creating chaos in the name of 'protesting' at times became insane, and suspecious,
Yes ... those who lost their lives during the 25th Jan - 11 Feb 2011 are martyrs ,,,, those who were killed while attacking national premises, setting fire,...etc are NOT
Manchester, UK
#17 Sep 22, 2012
well said EL ;) couldn't agree with you more ;)
The youth of Egypt both men and women died for likes of Morsi to be in the position he is now! Let's hope he doesn't forget them ;)
Manchester, UK
#18 Sep 22, 2012
I agree again ;) the thing is the brave people of Egypt who did fight, know they have 4 years to get themselves together and organised for the next election, that's if MB don't change that law too :(
Manchester, UK
#19 Sep 22, 2012
the people destroying Cairo were mainly paid thugs by the SCAF! They wanted the people outside to see that the Egyptian people were behaving like animals, whereas most were not.
I am not saying the riot mentality doesn't happen of course it does ( as we saw here in London last year ) but the majority were plain clothed army officers or prisioners let out of prison to cause mayhem!
Since: Jan 12
Location hidden
#20 Sep 22, 2012
w/salam man
You are complete wrong.......the egyptian hypocrite media corrupted your mind and the minds of majority of egyptians.
The ones who used to commit these actions, were the filthy police hidden in civil dress with other gang of criminals,they used to cause lot of anarchy actions in order to show the protesters as evi and corrupters.
ALL people who died after 11 february, are martyrs, they were the reason why the filthy army leaders were changing governments and made lot of pressure on them.
If those protesters were not always in tahrir, The scaf would scam the elections and bring Shafeeq in power.
Actually the regime of mubarak was the same untill mursi succeeded, it never changed
The army just beat the women and made them naked in Qasr el einy street, COWARD tantawy....coward army
I actually i dont support mursi now cuz he set all these filthy army bastards free.......wheres the justice??
Over 8000 egyptian people lost their eyes by police guns? wheres the justice to put the policemen in charge? They are free laughing on how they killed and injured the people
Since: Jan 12
Location hidden
#21 Sep 22, 2012
right sara, thats exactly what happened
They even sent their guys to play in mind of protests to leave the protests, when i was in tahrir, some guys would come to me and says" you want the scaf to leave the power? so who will lead egypt? i replied, a team of baradie abou el fotoh,sabbahi, he mocked them.......he also went for other guys and repeating the same stuff.
The scaf was sending his gangs to end protests by any price cuz this was the thorn in their back.
the coward MB used to attack protests too after they won the parliment elections,the pigs used to call the women who were beaten by army, wh'res that they went for tahrir for playing sex games
this was the hero army of tantawy, beating women at streets:
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An MSNBC host has had it with conservatives mocking global-warming alarmists every time it gets unseasonably cold or a snowstorm hits.
With a huge winter storm bearing down on the Northeast Thursday night, Chris Hayes griped about what he called the "strange, bizarre underworld of climate trolls" who enjoy pointing out the irony of global warming with each cold spell.
He referred to such skeptics as people "who delight being on the wrong side of history," according to the Washington Examiner.
"Of course, no one ever said that climate change meant it wouldn't ever be cold," Hayes squawked.
Most people recognize the difference between weather and climate, but tweaking the nose of global-warming fanatics during cold snaps is still great fun. And Hayes admitted that conservative commentator Matt Drudge has become adept at this particular brand of ridicule.
"I mean, Drudge has been incredibly powerful, I think, in this," Hayes grumbled. "Drudge has a thing about climate hoaxism, and he has been leading the charge."
But even Hayes has to admit that this has been a particularly brutal couple of weeks to sell any idea of global warming. Just about every part of the country — with the exception of Florida — was hard hit with winter storms throughout the holidays.
But the real lollapalooza came when a Russian icebreaker carrying global-warming scientists became stranded in thick, heavy ice off Antarctica — in the middle of the Southern Hemisphere's summer.
"The right wing had a field day, pointing and laughing at the global-warming believers, who — just to be clear — are only a group of scientists risking their lives for no monetary gain and little glory in order to help save the planet," Hayes groused.
Global-warming skeptics don't rely solely on weather-related events to make their case. They've also repeatedly noted that the Earth's temperature hasn't risen in over a decade, and satellite imagery has shown that the polar ice cap has actually grown by an astounding 29 percent in the last 12 months.
Some people — like Hayes — just can't admit they could be wrong. But in the meantime, baby it's cold outside.
Michael Dorstewitz
Latest posts by Michael Dorstewitz (see all)
- Fox News declines to renew some contracts and just revealed who got chopped - January 22, 2017
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2 posts tagged with beatemup.
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Boot to the head! And the knee. And the sternum. And then some punches.
Beat 'em ups and brawlers are a game style that goes back to the mid 80s. Your character moves across a horizontal level, left to right, slowly beating up each and every enemy you come across; progress is typically gated at several points, forcing you to defeat the current pack of adversaries before moving onto the next section. A fellow by the name of Ben Ruiz is working on a brawler and has spent quite a bit of time dissecting their gameplay. [more inside]
Dove of Brutality!
Bible Fight [Flash game]
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National rail operator
Facts about Netherlands
- Currency: Euro (EUR)
- Timezone: 1+ UTC
- Language: Dutch
The Netherlands is tailor-made for rail travel. The country benefits from a very efficient rail network with punctual trains running at regular intervals on all routes. All major Dutch cities can be reached in a train ride of 3 hrs or less from both Amsterdam and Rotterdam. There is just one domestic high-speed service, namely the 117-km stretch from Amsterdam to Breda which makes just 2 stops along the way (at Schiphol Airport and Rotterdam).
Eurostar is gearing up to launch a new direct service to the Netherlands in 2017. Trains will run from London to Rotterdam, Schiphol Airport and Amsterdam. But there's no need to wait till then to visit a country renowned for its tulips, windmills and laid-back lifestyle. London to Amsterdam takes less than 5 hrs by train, with just one easy change along the way at Brussels Midi station.
Dutch cities such as Amsterdam, Rotterdam, Utrecht and Maastricht all pull the crowds. They are all worth a visit, but make time too for smaller communities. Gouda, Delft, 's-Hertogenbosch and Haarlem are all great spots for day excursions or a weekend break.
The Netherlands enjoys excellent rail links to other cities in western Europe. High-speed Thalys trains link Amsterdam and Rotterdam with Paris. German ICE trains run regularly from Amsterdam and Utrecht to Cologne any beyond. And Intercity (IC) trains run every 2 hrs from Amsterdam and Amersfoort to Hannover and Berlin. There are direct night trains from the Netherlands to Munich, Basel and Zurich.
For overnight journeys to cities such as Vienna, Prague, Dresden, Berlin or Warsaw it is best to travel first to Cologne in Germany, where it is possible to join a range of direct overnight services to many destinations across central Europe.
Image credits: Curacao, Netherlands © Sorin Colac


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Continental Resources (NYSE:CLR)
Q4 2013 Earnings Call
February 27, 2014 11:00 am ET
John Kilgallon
Harold G. Hamm - Executive Chairman, Chief Executive Officer, Chairman of Finance Committee and Member of Nominating & Corporate Governance Committee
Winston Frederick Bott - President and Chief Operating Officer
John D. Hart - Chief Financial Officer, Principal Accounting Officer, Senior Vice President and Treasurer
Richard E. Muncrief - Senior Vice President of Operations
Jeffery B. Hume - Vice Chairman of Strategic Growth Initiatives
Jack H. Stark - Senior Vice President of Exploration
Steven K. Owen - Senior Vice President of Land
Leo P. Mariani - RBC Capital Markets, LLC, Research Division
Andrew Venker - Morgan Stanley, Research Division
Douglas George Blyth Leggate - BofA Merrill Lynch, Research Division
Brian Singer - Goldman Sachs Group Inc., Research Division
Marshall H. Carver - Heikkinen Energy Advisors, LLC
Noel A. Parks - Ladenburg Thalmann & Co. Inc., Research Division
Andrew Coleman - Raymond James & Associates, Inc., Research Division
Good morning, and welcome to the Continental Resources Fourth Quarter and Full Year 2013 Earnings Conference Call. I would now like to turn the call over to Mr. John Kilgallon, Vice President of Investor Relations. Please proceed.
John Kilgallon
Thanks, Vanessa, and good morning, and welcome to the Continental Resources Fourth Quarter and Full Year 2013 Earnings Conference Call. Joining me on the call this morning, with prepared remarks, will be Harold Hamm, our Founder, Chairman and Chief Operating Officer; Rick Bott, President, Chief Operating Officer; and John Hart, Senior Vice President and Chief Financial Officer.
Also available during the Q&A sessions are other members of the Management team including Jeff Hume, Vice Chairman of Strategic Growth Initiatives; Jack Stark, Senior Vice President of Exploration; Rick Muncrief, Senior Vice President of Operations; Steve Owen, Senior Vice President of Land; and Warren Henry, Vice President of Research and Policy.
In conjunction with the earnings press release and our call this morning, we have posted a summary presentation on the Continental website at www.clr.com as a reference tool. This presentation can be found in the For Investor section of our website. It is also posted within the web portal for your reference.
Today's call will include forward-looking statements that address projections, assumptions and guidance. Actual results may differ from those contained in the forward-looking statements. Please refer to the company's annual report on Form 10-K filed this morning with the Securities and Exchange Commission for additional information regarding these statements and risks.
Also in today's call, we may refer to EBITDAX, cash margin, adjusted net income per diluted share and PV-10. For a reconciliation of EBITDAX to GAAP net income and operating cash flows, a description of the calculation of cash margin, a reconciliation of adjusted net income per diluted share to GAAP net income per diluted share and a description of PV-10, please refer to the summary presentation materials I mentioned earlier that can be found at our website
With that, I'll turn the call over to Harold.
Harold G. Hamm
Thank you, John. Good morning, everyone, and thanks for joining us on the call this morning.
In 2013, the Continental team delivered another year of record performance, closing with a strong fourth quarter despite weather conditions and challenges in North Dakota and Montana.
We delivered on our commitments hitting key targets in terms of production, growth, capital efficiency, exploration success and proved reserves growth.
In just a moment, Rick Bott and John Hart will review our 2013 report card, specifically noting our 2013 goals and just how we achieved them. However, since this review of 2013, I'd like to think with you strategically for a moment about Continental Resources. We've built a leading E&P company with an exceptional track record of exploration success in the Sayer [ph] Hill, Bakken and SCOOP plays with more to come.
Since our initial public offering in May 2007, we've created outstanding value. In the process, we've participated in a historic energy renaissance in the United States that is literally changing our entire world.
This renaissance will have a profound positive impact on U.S. Energy Security and our economy. Continental is increasingly and rightfully recognized as one of the key leaders in American energy renaissance given our leadership in these strategic plays. However, apart from Continental's role as energy leader, how does the company continue to rank as the investment opportunity? What is the state of the company's investment thesis?
We see an outstanding opportunity to continue generating exceptional shareholder value for you. To understand our view, let's consider 4 points as we close 2013 in the context of the first year of our new 5-year plan.
Point one. Continental remains a high-growth company committed to exceptional production growth. Last year, we increased production, 39%, almost entirely through the drill bid and we're on track to achieve our 5-year goal of tripling production by year end 2017. That means by year end 2017, production should be roughly doubled what it is today. We're focused on strong profitable growth.
Point two. We have a tremendous growth platform, a multi-decade drilling inventory and premier oil and liquids concentrated resource place. We continue to add to our key leasehold positions in 2013, and now have more than 1.2 million net acreage in the Bakken.
As a leader in the play, we are transitioning in the full development mode so we can maximize the payback on our highest return lease holds. This is the Ears Back program in Antelope.
In SCOOP, we increased our leasehold almost 404,000 net acres at year end 2013. We're seeing very strong results as we delineate the play with exploratory
Bakken and SCOOP exemplify our focus on the superior value of oil and liquids, although the run up in natural gas prices in recent weeks demonstrate the option value we have if natural gas prices strengthen in future years.
SCOOP returns should be even stronger in future years if we get the same higher natural gas prices. Still, our value cornerstone is oil. 2013 production was 71% oil and our year end 2013 proved reserves were 68% oil.
Point three. Continental is an exploration company, it's just in our DNA. In 2008, with the first 3 explorers, the first bench of the Three Forks in previous commerciality. In 2013, we repeated this by exploring with productivity and density test to lower benches in the Three Forks.
As our Hawkinson density test demonstrates, the Three Forks package is larger than anyone knew just 2 years ago. And it should be a significant contributor to our production in proved reserves growth in the years ahead.
Exploration is also the key to SCOOP. In 2012, at the time we were clearly executing so well in the Bakken, many asked why Continental is spending CapEx on the new geologic concept in the SCOOP and other plays. The answer is now clear.
As explorationists, we're always looking for the next opportunity to apply our experience in new technology to create value that SCOOP fits the bill.
SCOOP today is recognized as tremendous additional growth platform, and we're more excited than ever as we delineate SCOOP to the South and expand our footprint into play. SCOOP well economics are on par with the Bakken, and we're just ramping up our extended lateral growing program here in Oklahoma, which we expect will boost return further.
In addition to these 2 cornerstone plays, we're actively working on new opportunities to acquire experience in lays drilling and completion technologies to new growth opportunities.
Finally, point four. Our business model is focused on profitable growth by maximizing returns and cash flow.
One element this effort involves operating excellence, constantly working to operate more efficiently and at lower costs, while challenging ourselves to better our safety and environmental performance.
As noted, we're exploring not only with the drill bid, but through the application of new technology. 2013 was a tremendous year on all counts. Our teams are developing and managing new markets in maximizing the value of our production. They are working to deliver as much value as possible from every barrel in Mcf to the bottom line. We are continuing to work to develop additional new markets for oil and natural gas production.
So we believe Continental's value creation opportunity is as strong as ever. Our current 5-year growth plan is just the beginning of what we see as a multi-decade growth trajectory based on premium inventories, strong production growth, strong cash flow growth and operating excellence.
We're proud of Continental team's 2013 achievements, which translate directly and increase shareholder value.
We had some tough weather challenges towards the end of 2013, but we're a longtime player in North Dakota and we're not complaining about the weather. The extended cold weather brought natural gas prices out of the door into where they're respectful again and prices maybe there for a while, considering storage. So we're not complaining.
So now the key question is, what's next for Continental? We'll be reporting our progress to you through the remainder of the year. But please make plans for our 2014 Investor Day, which we're tentatively scheduling for around mid-September again in Oklahoma City. Stay tuned as we get closer and announce the date, to put on your calendars. It will be a content-rich download on our key exploration and development projects and growth strategy, so you will certainly want to attend.
With that now, I'll turn the call back over to Rick. Rick?
Winston Frederick Bott
Thanks, Harold. He mentioned in the report card in terms of 2013 as a whole, the Continental team certainly delivered it's A game again this year.
We set out to grow production 35% to 40% over 2012 then increased that goal to top of the range. Final results, 39% year-over-year production growth.
We ended 2013 on a strong note despite challenges in December with severe winter weather as we discussed in our February 6 press release.
Production of 144,250 barrels of oil equivalent per day for the fourth quarter, was 35% above the year-ago quarter and 2% above the third quarter of '13.
Currently, productions recovering nicely as now approximately 150,000 barrels of oil equivalent per day. Crude over here reserves at year end '13 reflected strong drilling programs in the Bakken and SCOOP this past year. We reported record proved reserves of 1.08 billion barrels of oil equivalent, a 38% increase over year-end 2012.
The Bakken now accounts for 68% of proved reserves and our drilling acceleration in SCOOP has increased its reserve contribution to 20% of proved reserves in less than 2 years.
In value terms, PV-10 for our total proved reserves was 22 -- 20.2 billion at year end 2013, a 52% increase over the PV-10 of 13.3 billion at year end '12.
We're solidly on track to achieve our 5-year growth targets with 1 year in the bank.
With regards to our 2013 highlights, I'd like to concentrate on several significant achievements in exploration and operations. What we started in 2013 will continue to have impact and be key catalyst in our 2014, '15 growth picture.
First, we set out in late 2012 to implement an ambitious 22-well Lower Three Forks exploration program to demonstrate commercial productivity across the Bakken play in North Dakota. The other part of the program was 4 multi-well density drilling tests to help us determine optimal well spacing in the Middle Bakken, first, second and third benches of the Three Forks.
We completed all 22 productivity wells and are now monitoring production history to build decline client curves for the lower benches.
In the meantime, work continues on the density testing. In November 2013, we announced initial results from the first test, the Hawkinson project in Dunn County. The Hawkinson project involves 3 legacy wells in the Middle Bakken and first batches of Three Forks and 11 new well space 1,320 feet apart within zone and offset vertically 660 feet.
The new wells are in the Middle Bakken, first, second and third benches of the Three Forks.
Based on the first 120 days of production, average production for 12 of the 14 wells is on a trend approximately 50% higher than the company's 603 barrels of oil equivalent model for the North Dakota Bakken.
The 2 exception wells are in the TF3 zone. They were recently put on pump and are producing on a trend below the 603 barrels model and improving.
Given the early nature of the production, these trends, of course, could change over time.
The next 3 density tests are being completed, the Tangsrud, Rollefstad and Wahpeton. We had hopes to report initial results for the Tangsrud and Rollefstad on this call, but the severe winter weather delayed that schedule. These 2 projects, which are testing again the 1,320-foot spacing should be ready to report on our May earnings call, if not earlier.
Initial results from the Wahpeton, which is testing the 60-foot spacing between wells were also delayed and will likely be ready by mid-year.
Based on our positive results to date, we've begun drilling 3 additional 660-foot spacing density test in the Hartman, Lawrence and Mack units, which are on the slide, supplemental to this presentation.
So we're very pleased with our density testing program. The Hawkinson area in Dunn County was a good test and the location was strong production potential.
Based on the results from all 7 density tests, we plan to be ready next year to accelerate full-field development in multiple areas of the play. However, we received a lot of questions since our announcement last night, so let me pause just a moment to comment on the deeper benches to answer some of these questions.
I guess, I didn't realize that Hawkinson had quickly become such a household name. But testing these deeper benches has not been about whether they meet our 603 model, some do and some don't. But on average, they fit the distribution of other wells in a given area.
The key for us is that we have established commercial production over a very large area. It's always been to define the component parts of the petroleum system to determine how best to proceed with full-field development. So we cost-effectively get the most out of these reservoirs.
We believe future technology advances, as well as efficiency gains will only increase the commerciality of these zones within this large footprint.
So it's also important to understand where we are in our overall Bakken exploration program, so let me step back for a moment and provide some context.
We're nearing the end of really a 6-year process, where our primary goals are to expand the play geographically and vertically, to de-risk of growing leasehold position and to hold core leasehold by production. Information gathering and de-risking has driven this process. We are now beginning to shift into full-field development starting with Antelope, as Harold mentioned, where we have more opportunity to truly maximize efficiencies and rates of return.
Now looking -- again, looking back over the same period, all Bakken operators needed to build up execution capability including drilling rig fleet, service providers, train new crews, construct gathering and takeaway capacities, as well as build basic infrastructure for rapidly growing communities and a growing workforce. There were a lot of growing pains to get through.
These macro issues are behind us now. The industry and infrastructure have, for the most part, caught up with the Bakken. Drilling rigs have leveled off at 180-or-so combining in Montana and North Dakota. Gas processing capacity is catching up, rail transportation systems have been built out and additional pipeline takeaway capacity is on the horizon.
Basin-wide production can, therefore, continue to grow because of all of this investment. This makes huge a difference in terms of communities in northwestern North Dakota. For example, with more gathering capacity, we can get many trucks off the road and reduce congestion.
More gas process capacity enables the industry to reduce flaring. But the progress we've made is also critical in terms of optimizing efficiency, safety and environmental stewardship in our operations. We're making huge strides.
Moving into full-field development in Antelope provides yet another opportunity to improve on an already great game in the Bakken. Our operating teams did a tremendous job managing the growth in the past year, lately under challenging weather conditions. Their performance in 2013 was simply outstanding.
Now let's discuss well costs and operating efficiencies to provide yet another example. Our 5-year goal was to reduce well costs by an average of 3% to 5% per year, and again, we did A plus work in the first year.
Our 2013 goal was to reduce Bakken well costs from $9.2 million to $8.2 million by year end or 11%. We made so much progress in the first half, we lowered the goal to $8 million and we hit that target in the third quarter. So the first year, we have a 13% reduction in well costs.
Our goal for year end 2014 is $7.5 million per well for our standard design Bakken well or another 6% reduction.
Now we've also announced we'll be trying an alternative completion designs on about 20% of our Bakken wells this year, so their costs are likely to be higher.
The other key exploration achievement I'd like to highlight involves SCOOP. We only introduced a new play at our 2012 Investor Day, just 17 months ago. We told you the goals for 2013 would be to continue expanding our leasehold position while increasing our understanding of SCOOP's geology. We made tremendous progress last year.
As Harold noted, we increased our leasehold position significantly. Our key emphasis in SCOOP for the next couple of years will be delineation and appraisal of our leasehold position.
Just over half of our operator rigs are drilling extended laterals, an important step in improving already solid returns. We're also planning to do spacing tests and maybe wandered a couple density pilots later this year to prepare us to accelerate into development mode in future years.
Fourth quarter 2000 in production in SCOOP was more than triple production in the final quarter in 2012, which really tells a story. Although we're early in the learning curve in SCOOP, we plan to reduce well costs there as well. Our year end 2014 target is a blended average of $8.7 million for a 1-mile lateral well, including wells in both the condensate and oil fairways.
This short lateral well cost target compares with a fourth quarter 2013 average of $9.1 million for a typical exploration well in SCOOP. This is a little higher than we discussed early last year because we have increased the number of stages in our standard completion design.
Our year-end target for extended laterals is $13.5 million per well, and when we eventually transition to development drilling, we'll have a greater opportunity to reduce well cost.
Before handling the call over to John, let me emphasize that 2012 was a watershed year for Continental Resources as we grew the management and technical teams in preparation to be a significantly larger operator and producer by the end of 2017.
By the operating and financial numbers, it was a great execution year, it gives us even more confidence in achieving our 5-year goal.
Behind the numbers, we're also putting a lot of effort recruiting and integrating new people and skill sets in the Continental's organization, but at the same time, working hard to preserve the key traits that made this company so successful in the past 47 years, its innovation and entrepreneurial spirit, always alert for the next opportunity.
The love of exploration with prudent risk-taking, integrity, hard work and striving to be among the best wherever we work.
We are absolutely determined to preserve these values as we become a larger, more complex company, growing towards the achievement of our 5-year goal.
With that, I'll just turn the call over to John.
John D. Hart
Thanks, Rick. I'd like to look this morning at some of our other performance and financial metrics, especially as they relate to our 2013 guidance.
We committed to achieve and effortly revise production goal of 38% to 40% growth with a CapEx budget of $3.6 billion, and we were very disciplined with our spending throughout the year. The final number was 39% production growth and $3.57 billion in non-acquisition CapEx, which was $30 million under budget.
The key element in achieving this goal was -- it was improved operating efficiency. Rick noted the decreased well costs in our year end 2014 targets. Lower well costs continue to be an essential element in our overall capital and operating efficiency efforts.
We had similar results with operating expenses. Our revised goal for production expenses was a range of $5.60 to $6 per Boe of production, and we came in at the bottom end of the range, $5.69 per Boe for the year. We were a bit higher than this for the fourth quarter, but that simply reflected the deferred production volumes and temporary inefficiencies associated with weather.
Our target for cash G&A expense was $2 to $2.50 and we again came in at the low end of the range at $2.07 per Boe. Non-cash equity compensation was right on target at $0.80 per Boe.
Finally, DD&A was projected to be in the range of $18.50 to $19.50 per Boe, a positive reduction from the original guidance of $19 to $21.
For full year 2013, we achieved actual results of $19.47. The fourth quarter result was slightly higher due to the mix of wells completed and higher DD&A rates as we've focused on delineating the extent of the play, as well as testing the upper Bakken shale in multiple locations.
While some of the upper Bakken shale tests were promising initially, their decline rates overall were steeper than normal for the play.
We expect several related factors to reduce DD&A in 2014. First, the completion and production of our Tangsrud, Rollefstad and Wahpeton density projects in the first and second quarters.
Additionally, development drilling in the Antelope part of the play and further exploratory drilling in [indiscernible] . The average oil differential for 2013 came in at $8.23 per barrel, based on year end volatility in prices and spreads in the fourth quarter. This was lower than 2012, but slightly over the guidance range of $6 to $8 per barrel for 2013. Volatility will be a continuing challenge. Our guidance for 2014 is an oil differential range of $8 to $11 per barrel.
On the other hand, our natural gas differential was a premium with $1.59 per Mcf for 2013, $0.09 above the top end of our guidance range of $1 to $1.50, reflecting the richness of the gas we produce.
In terms of 2014, we reiterated guidance in yesterday's press release. We remain confident of hitting the 26% to 32% production growth target despite winter weather challenges in early January. We continue to roll in new hedge positions to support the stability of our drilling program and production growth.
We continue to work the balance, our derivative positions with our physical deliveries of oil as much as possible. We believe our utilization of financial hedges is a prudent measure, providing stability and operational flexibility for executing on our growth and capital plans.
Please refer to our 10-K filed this morning for a summary of our positions at year end. Next, let me add some color to Harold's point about our ability to source capital efficiently to support our growth strategy. One objective from the finance side of the business has been to reduce borrowing costs and expand our capital options, taking advantage of the flexibility inherent to Continental's strong balance sheet.
Clearly, our track record of exceptional operating performance is critical to this. We believe this record was an important factor in S&P and Moody's upgrading Continental to investment grade status in 2013, which obviously indicates we're on the right track in terms of disciplined growth.
Continental possesses long life, high-quality assets that support significant growth for years to come, attaining investment grade, not only a test of the quality of our assets, but it would also enable us to finance growth with greater certainty and to access broader markets.
We've also put in a great deal of effort in areas that are difficult for investors to depreciate, because they are behind the scenes. We've made significant strides in the past 18 months to cost effectively build the internal infrastructure we will need at the year end 2017 when Continental is 3x the size it was at the end of 2012.
This type of preparation is taking place throughout the Continental organization and gives us increased confidence that we will hit our 5-year growth goals.
We want to be sure and thank our teams for their efforts and commitments to our shared goals.
In summary, 2013 was a significant year in the Continental growth story. We have dramatically changed the company's profile in the last several years, transitioning from a small, independent oil company focused on the emerging Bakken play, to one of America's larger independents with strong operating footprints in 2 leading resource plays.
2014 is shaping up to be another year of strong growth in production, proved reserves and cash flow, underpinned by a strong balance sheet.
With that, I'd like to turn the call back over to our moderator, for the question-and-answer period. Thank you.
Question-and-Answer Session
[Operator Instructions] And our first question comes from Doug Leggate with Bank of America.
John Kilgallon
Vanessa, let's go to the next one. We'll see if Doug can get back in the queue.
We now have a question from Leo Mariani with RBC Capital Markets.
Leo P. Mariani - RBC Capital Markets, LLC, Research Division
Guys, can you speak to kind of current SCOOP EURs? It looks like your production there has kind of outperformed versus your curves you had out there. Just wanted to see whether those were kind of a year end '13 the reserve report?
Richard E. Muncrief
Yes, Leo, it's Rick Muncrief. In the gas cost, you're looking about 1.2 million barrel equivalent, and then in the oil fairway, you're looking at about 650 MBoe.
Leo P. Mariani - RBC Capital Markets, LLC, Research Division
I guess, are those all on kind of short lateral wells, I'm guessing?
Richard E. Muncrief
That's correct. That's -- those are all assuming the 1-mile laterals.
Winston Frederick Bott
Leo, just to follow-up on that. We're -- as you guys, you've seen it from our release, we're drilling a lot, a higher percentage of these cross-unit wells. So it's going to later in the year before we actually come out with EURs for cross-unit wells.
Leo P. Mariani - RBC Capital Markets, LLC, Research Division
All right. I guess, just looking at the Bakken, obviously, you guys talked about weather impact. Is it possible for you guys to kind of quantify what you saw in the fourth quarter in terms of kind of what your lost? And it sounds like maybe you didn't get as many wells online in the Bakken in the fourth quarter. Could you -- do you have that number for us as well in terms of net wells completed?
Richard E. Muncrief
Yes, Leo. That number would be approximately 5,000 barrels a day equivalent for the quarterly average.
Leo P. Mariani - RBC Capital Markets, LLC, Research Division
Okay. And I guess just the number of wells you guys brought on in the fourth quarter on a net basis in the Bakken, do you guys have that?
Winston Frederick Bott
We bought on 37 net, 163 gross wells, IP, 1,800 barrels of oil equivalent per day, for the total North Dakota. Montana, 14 net, 17 gross, 600 barrels of oil equivalent per day, average IP.
And our next question comes from Drew Venker with Morgan Stanley.
Andrew Venker - Morgan Stanley, Research Division
In the Bakken, can you talk about what you've seen so far as you experiment with different completions?
Richard E. Muncrief
We're still early. We have tried several things. First off, we've tried several hybrid jobs, that's where you start with more of slick water type design and then transition to a linear gel onto a cross-linked gel and increase your profit concentration. We've seen a scattering of results on that. We're encouraged by that. We've also pumped a handful of slick water jobs. The results we've seen thus far are once again somewhat mixed, and we see some increased productivity certainly, probably, more so in the Middle Bakken than we do in the Three Forks thus far. But I'd also warned that we just have a handful of results, and there'll be more we'll talk about later on. And then the last thing that we have done is we've increased proppant. And one of the proppant projects you'll hear about in the near future is the Rollefstad, and that's one that where we have been [indiscernible] our stimulation designed by more proppant per stage on all those wells. And so, still has results and we will talk about later in the year. But that's we're at. As we've announced earlier, we're going to allocate about 20% of our capital program to try something different in our base design and we're off to a great start on that. So the acceleration of that will hopefully allow us to really hone in on the water of ultimate design needs to be.
Andrew Venker - Morgan Stanley, Research Division
Okay, that's helpful. And then in the SCOOP, can you compare the recent results to your expectations? I guess it would be helpful in particular if you could talk about how the 2-mile laterals compared to the single mile lateral results.
Richard E. Muncrief
Well, what we've seen thus far as that we've talked about is from a total comparison, you're looking at about a 50% increase on the CapEx and we're seeing 2 -- to slightly over 2x the productivity from a production rate and reserves. So we're extremely happy with the results we've seen thus far, and we think that's absolutely the way to develop this field over the long haul.
We now have a question from Doug Leggate with Bank of America.
Douglas George Blyth Leggate - BofA Merrill Lynch, Research Division
Guys, if I can go back to the SCOOP real quick. So one of your competitors, obviously the Newfield, does come out with another upgrade. To their type curve it looks like yours is about, I guess, a couple years old now. Are we going to see you guys update your EURs on a per well basis? And how should we think about what the SCOOP looks like in a go-forward basis relative to the 2012 Analyst Day?
Richard E. Muncrief
Yes, Doug. It's Rick Muncrief gain. We will be updating our type curves. And as Harold mentioned, the Analyst Day that we're going to have in September, we think that you're going to really be quite pleased with everything you'll see there. But what we have now is we have a handful of wells with the extended laterals, some of those are just over 6,000 feet and we have some others that are 9,200 feet. And so we've got a smattering of different lengths of laterals. What we see, a very strong correlation on, is the lateral foot, the recovery per lateral foot is pretty predictive. And so from that, we think that we'll be able to update our type curves, I think you're going to like what you see.
Douglas George Blyth Leggate - BofA Merrill Lynch, Research Division
Oh, okay. I guess we'll wait a couple of months about that. While I have you down, I wonder if I could ask you the same question about the Bakken. We haven't really heard you talk much about how the experimentation and completion design is, it might be impacting EURs and, ultimately, your development plans in the EON. I guess the Hawkinson is probably a good example of how this is going to play. Can you give us an idea as to whether or not you still think that you're -- I guess, you've stopped with 603 now for quite some time. Has the development area for Middle Bakken Three Forks as an average, how should we think about completion changes and ultimately, the upside or maybe the risk factor to 603? A little bit there.
Richard E. Muncrief
When we've stuck to the 603, I believe we laid that out for the first time in mid-2011. And so coming up on 3 years of that 603 model, and we really haven't changed it-- we haven't seen the need to change it. It seems like it's -- we're been able to deliver the programs that we have planned for. That being said, as we get into more of these multi-well unit developments, we're going to have a lot of factors. We're very bullish, obviously, on the Lower Three Forks as we've mentioned in our press release and what the results we're seeing for the Hawkinson. We're seeing the improved drilling cost, we're extremely excited about that. And then, the completion techniques that we're trying, we're going to get to an answer that we think is the way to ultimately develop the field. And so once again, I think you stay tuned. We're going to have enough information. It's real hard sometimes to be patient to wait on that information, but I think that's what is going to be so key for us, is that patience.
Harold G. Hamm
And one area too, Doug, that you might keep in mind, we're just now starting one of the development of the funded better areas of our whole Bakken acreage and that's Antelope, so what we're calling here Ears Back. So that's large area, and so that's going to also impact our model.
Douglas George Blyth Leggate - BofA Merrill Lynch, Research Division
Guys, I don't want to be greedy with time here, but real quick, let me just follow-up. So under the links for the guidance you gave on production, is it fair to assume that when you laid our your original 5-year plan a couple of years ago, your first couple of years are running ahead of that guidance, but your completion seems to be improving your EURs, I guess, and the SCOOP are probably going to be improving. Is it fair to say there's probably some upside in production targets at this point?
Winston Frederick Bott
Well, I guess it all depends on price, doesn't it Doug? I mean, at the end of the day, we put out what we thought was a reasonable program for our 5-year plan. And we told you when we put that out that we were going to try to hit the ground running because we felt there was an opportunity for value capture and in the near-term, and to also prove some key things that we're going to move the needle in terms of total resource capacity in the Bakken. And just as a reminder, the 5-year plan really only required the first bench and the Middle Bakken to deliver the 5-year plan. And so everything that we're doing in SCOOP, everything we're doing in the lower benches is additive to the 5-year plan. But ultimately, the 5-year plan will become sort of secondary in terms of the full-field development, we start rolling into that. And so is there upside? There is upside but there's always risk on the downside too. So we're still pretty comfortable with that 5-year plan. We think getting ahead of it the first year gives us versatility in terms of making sure we can deliver it and now we've got optionality in the different play in SCOOP, and it's paid out for us in terms of the weather. The weather wasn't as impactful in SCOOP although we did have some impact, but it allows us to still hit that production target that we promised our investors.
Our next question comes from Brian Singer with Goldman Sachs.
Brian Singer - Goldman Sachs Group Inc., Research Division
Two questions. The first is on the rail side. Given that all that's gone on with regards to the potential for having to retrofit, refurbish or replace some of the tank cars. Can you just talk about your expectations and the conversations that you're having with your rail providers for the timing and the cost to producers of potential changes to the tank cars? And do you see a potential period of disruption even if it's temporary?
Jeffery B. Hume
This is Jeff Hume. And we have had conversations with all of the rail transporters that we're using both the rail road and the car manufacturers. They are currently going through design studies now of what -- where they will go with those cards, you saw the Burlington Northern Santa Fe and court orders in for over 5,000 cars with 2011 designs with some modifications. I think they'll come out with those quickly. From talking to the DOT, I think that we'll be more than likely brought in over a period of time to accommodate continued movement of the crude oil as we're bringing new car and upgrade it. There's quite a few of those new-styled cars already on the tracks. Most of the refiners that have added those cars that we deal with are using the new cars already. So we feel pretty comfortable here at Continental with the shipment of our crude oil continued. We applaud the scrutiny, I think they're barrel safety is key to continued use of rail for movement of oil is growing and working well. So we applaud the moves they're making. We think it will be managed in a way that will not interrupt our business and will be in good shape.
Harold G. Hamm
In addition to that, Brian. We have a lot of new pipes coming on this year and so we think the combination of that, make sure that we get our oil out in good shape.
Brian Singer - Goldman Sachs Group Inc., Research Division
Great. And then my second question is, in the press release, when you're talking about the Hawkinson results, I think you indicated that it validates your vision for full-field development of the Bakken. And I recognize that you've got more pilots less to fully validate your vision. But can you just talk more specifically about that vision when applied to spacing, number of zones and then the differentiation across your acreage?
Winston Frederick Bott
Well, it's real simple, Brian. In fact, I'm going to invite Jack to comment on, add to these comments. We think we've basically proven commercial productivity over a very large footprint at 3,800 square miles. We also recognize, as we've told you guys all along, that the rocks might be a little bit different in different areas. And as a rule, the deeper benches, second and third bench, come in pretty much in line with other wells in that area. We've talked about how the rock quality changes and the saturations changes as we go down into the interval, so I think we've talked about that numerous times. But the bottom line on this is there's commercial oil in the second and third benches, and we would not be prudent if we left it behind. So it's going to be a part of our full-field development, but that's going to be kind of an area-by-area sort of basis and we think the economics and rate of return in some of those deeper wells compete with anything we've got. So you probably will see us based on an area basis. Don't know what the exact spacing will be. We've got, as you say, we've got 6 more pilots to get under our belt and then we need production history from those to see how things change over 6 months and a year before we make those final decisions by area. But we think it's significantly added to the recoverable resource of the basin in the entire petroleum system. Jack, can you add to that?
Jack H. Stark
No, I think that really covered that well, Rick.
Brian Singer - Goldman Sachs Group Inc., Research Division
And do you view Hawkinson as a sweet spot within that -- within your acreage based on what you've seen?
Richard E. Muncrief
This area here, we do see above average production in the Hawkinson unit. But as far its character, as far as Three Forks is concerned or reservoirs, no, it's pretty much similar to what we see across the basin here as to the Lower Three Forks.
Winston Frederick Bott
I'll just add to that, Brian, that certainly because we've got the data now and we have another 6 months worth of production, it becomes a prime candidate to move into full-field development but so do the other 7 areas that we're doing these pilot programs on.
Richard E. Muncrief
Yes, and the key thing here is that this is only full-field development project that is actually -- this is the first full development in the field. We've got well bores in 4 zones, and we're seeing that all 4 zones are contributing and they're contributing at just great rates. I'm very encouraged of what we're seeing here and the results that we have in that third bench. To me, extremely encouraging here. It fits right in line with our expectations from what we know about the geology. As Rick mentioned, we do see variations in the rock as we go deeper. And so, I'd just say that this is a great start for us to get a clear vision of what it takes to fully develop this unit, or this field, and basically, leave no oil behind.
Our next question comes from Marshall Carver with Heikkinen Energy Advisors.
Marshall H. Carver - Heikkinen Energy Advisors, LLC
On the SCOOP play, you've got a good job of building the acreage position over the last, probably, several quarters. Have the recent acreage adds been in the sort of original de-risk footprint or they've been more in the expanding part of the play to the South? And what percentage of your acreage would you say is now in the oil window versus the condensate window?
Steven K. Owen
Yes, this is Steve Owen. We have put together a very substantial position throughout the entire play. We really aren't well into providing any additional data or detail at this point as to our leasehold position. Suffice it to say, we're continuing the acquire and lease in all of the key areas throughout SCOOP.
Richard E. Muncrief
And with regards to just what is, what's in the oil window, condensate and gas, approximately, right now we'd say of, maybe, about 40% of the position is in the oil, 40% is in condensate and the rest in more of a gas area.
Winston Frederick Bott
But Marshall, in terms of the play -- and we kind of define the play and I think we're pretty comfortable that we've got a significant, a good portion in all the good parts of the play. So I think we're pretty happy where we are. We've got some good acreage.
Marshall H. Carver - Heikkinen Energy Advisors, LLC
Okay. And I guess a follow-up, how many of the 2014 Bakken wells will be lower bench Three Forks versus Three Forks 1 and Middle Bakken?
Jack H. Stark
I was going to say, right now, we're probably in that range of 030, 35 right now. We're probably be in these lower benches. It varies as the year goes on here as we adjust some of the program, but -- and will be adjusted on the results.
Marshall H. Carver - Heikkinen Energy Advisors, LLC
Okay. That will be 30 to 35 net wells?
Jack H. Stark
Richard E. Muncrief
Net or gross?
Marshall H. Carver - Heikkinen Energy Advisors, LLC
Will that be a net or gross?
Jack H. Stark
That will be a gross. Well count is about 24 net, I think is where we end up.
Our next question is from Noel Parks with Ladenburg Thalmann.
Noel A. Parks - Ladenburg Thalmann & Co. Inc., Research Division
I want to start with more of a broad question about the Williston overall. And I've been hearing some producers talk about what the actual trajectory of the basin's production growth is going to be. I think that -- thinking was that there'd be a very steep rise to a peak production level maybe later in the decade. But I've heard some people say that, just as you mentioned, the infrastructure has caught up in the play. Sort of where do you see the peak? And is it possible that it might be sort of a more gradual peak with a longer plateau, instead of sort of us continuing at this sort of break-neck pace we've had for the basin?
Winston Frederick Bott
Well, I think our projection is the same as it was. Our projection was that we saw a rise after about 2 million barrels a day overall. And I think we're sticking with that. We've seen kind of leveling off and even a little drop, if you will, in rig count up there. North Dakota, we had locked 171 rigs, last time I looked at it. And we think that, that's because the HBP acreage, most of it's HBP-ed. Operators are going to slack down a little bit. Winter weather, of course, had some effect this year with people that had been up there too long. So I think it may be a little bit more gradual as we see proppants build out and things like that. But it's a very measured approach that's going on by operators up there. We've taken that approach. People are following our lead and we think it's the responsible thing to do.
Noel A. Parks - Ladenburg Thalmann & Co. Inc., Research Division
Great. And I wanted to ask about in the pads after the Hawkinson, the Rollefstad, and the Wahpeton and the drilling. I remember with the Hawkinson, you had a faster-than-planned cycle time in the drilling and I wondered if you'd seen those same pace continue on with the newer pads, and just what that might look like going forward.
Richard E. Muncrief
Yes. We did see cycle times, really attractive cycle times on all 3 of the pads, and it's a little bit of a shame that we've got a little bit of the weather impact. We're not making excuses, getting out of those completed proton. But certainly, from a cost perspective, it's very impactful. And the reason it's impactful is when you really start looking at, as Rick and Jack and Harold all have alluded to, in the lower benches is -- you're seeing the ability to go in and harvest this oil at a very attractive, economic picture. For instance, we've looked at some of the Lower Three Forks and the TF3 on the Hawkinson. And even though 2 of the wells are still under the 603 model, as we suggested in our earnings release, we still have seen economics on those 3 wells that suggest 35% to 40% rate of returns, and that's very attractive to start looking at a $7.5-million well cost from a pad. And so we see the cycle times continuing, you see it really across the board. We don't talk much about our outside operated activity, but we see it with some other operators' well, which helps us because it drives those costs down. And the outside operated have purpose, sees as well. So I think what you're going to see is continued economic enhancements over the next 3 to 4 years without any doubt.
[Operator Instructions] Our next question comes from Leo Mariani with RBC Capital Markets.
Leo P. Mariani - RBC Capital Markets, LLC, Research Division
Guys, I just have a follow-up regarding your oil price realizations. Just kind of looking at the fourth quarter of 2013, it looks like your oil price realizations were down, roughly $13.50 by my math here. And just kind of looking at some of the benchmark pricing, I'm seeing that Brent was down roughly $1 from 3Q to 4Q and LLS was down by $9 and WTI was down about $8.50. But I guess, your realization was kind of down more, I was just looking for maybe some color around that if you, guys, had any.
Jeffery B. Hume
Leo, this is Jeff Hume. Several things happened that put pressure on us in the fourth quarter, one was the widening refinery changing from sweet crude to Canadian bitumen, around 200,000 barrels a day of light sweet market went out of the pipeline delivered market. And so it's putting more pressure on the rail. The good news this quarter, we're opening up more pipeline spaces line and Bridgeline 9 opens up to the Great Lakes refinery sector putting more out there. We have the Keystone South working thus we're leaving cushing allowing more oil to flow down into the cushing area. And refineries are coming back on. We had some early turnarounds due to a couple of fires up in the Rocky, the Northern Great Plains region, and then up in Minnesota, so they did some early turnarounds. All of that hit together, and at the same time, Syncrude units were running at capacity in Canada. So there's a lot of oil showed up, and at the same time, we had some restrictions that occurred, most of them were unplanned, a couple of them were planned, and so a full shock in the system, but that's being taken care of. As Harold said, we have the Pony express pipeline that's going to be coming on, taking around 210,000 barrels a day out of the basin starting in the third quarter. Will give us more relief. And we're seeing an improved rail service up there. So opening more and more markets, and most of that is from unloading side of the rail, it's not loading at the basin, it's unloading at the refineries, we're seeing improved infrastructure built out there. So I think we'll see smoother, we're seeing the rail compete more with the local crude pricing. And so I think thing's are going to be picking for us and that's -- so we've put the guidance set that we have and we think we can hit that.
Leo P. Mariani - RBC Capital Markets, LLC, Research Division
That's great color. I guess, as with respect to that obviously you've got a bit of a range on your differentials in your guidance. I mean, obviously market conditions are hard to predict but all things being equal, would you expect to see improving realization as we get maybe later in the year as some of these pipes come on, and then maybe some further improvement potentially in '15?
Jeffery B. Hume
I do. I think the continued -- just looking out in front of us, I think we should be seeing continued improvement. We're working on several fronts as all the operators out there. One is the quality of our crude, that words are getting out that it's high quality in value. I think we'll start seeing improved competition for our crude at the other end of the line as we get more pipeline south that's going to lower cost and bring on competition, a little more competition for that crude. Transportation cost will eventually work down as you build out that infrastructure, so I agree.
Our next question comes from Andrew Coleman with Raymond James.
Andrew Coleman - Raymond James & Associates, Inc., Research Division
Just on the Hawkinson pad wells, and the subsequent ones, I guess, how much improvement have you all seen, I guess, in terms of start to finish times from site preparations to tying in the wells? And how should I extrapolate that, I guess, into my NAV model going forward?
Richard E. Muncrief
Good question, Andrew. What we have seen is we've seen in the Hawkinson, for instance, we saw about a 10% improvement over what we had modeled. The cycle time being from start to finish, and that was with some complex microseismic, we had a lot of things along the way that we did there that -- but so I think that what you can look at is site preparation is really not an issue. We've got that pretty well done ahead of time, and then we start looking at just actual cycle times on the big pads, big pads being greater than 8 wells per pad. We're looking at about a 20-day to 22-day average on those from spud to rig release to the next well. And then in some cases, and it depends on the pads, we can do some simultaneous operation. So we're doing everything we can to accelerate that for a couple of reasons and obviously, to bring out production on, but also to accelerate our understanding. So we can probably provide a little more color later on as we get into it. Some of these will be sites-specific.
Andrew Coleman - Raymond James & Associates, Inc., Research Division
Okay. And so then thinking about, I guess, you're going to get average as 22 rigs this year, so maybe another -- as Ears Back kind of gets there, and gets more data probably about the fall, maybe we'll have some view by then on the in terms how rig count might stabilize and start declining as you ratchet up the activity?
Richard E. Muncrief
Yes, that's correct. Right now, for instance in antelope, we're at 3 rigs today, we'll have a fourth rig probably within the next 4 to 5 weeks. A fifth rig in the second quarter. And hopefully, a sixth rig in the third quarter.
Andrew Coleman - Raymond James & Associates, Inc., Research Division
Okay. And do you anticipate -- as you test the 20% wells made bigger fracs, are there sort of science work that you would see any, I guess, leakage, in terms of time? The other way, as you change the ultimate completions style? Or anything you really get in that window?
Richard E. Muncrief
No, I think we can. If you look at some of the larger, especially the slick water fracs, it just takes a little more preplanning upfront, but we've got a team that's doing that. We're rolling it, right now, with 8 stimulation crews. And so we've got the operating capabilities to handle that plan effectively, source it. And so I don't think you're going to see much slippage on time. We will execute.
Andrew Coleman - Raymond James & Associates, Inc., Research Division
Okay, all right. And then last question I had, puds in the reserves report, I guess, were approaching 60% I think by year end. I guess how much higher can you see that going? And I guess, does that point you toward a minimum sort of well count to kind of stay up on that wave as you continue exploring the resource up in the Bakken?
Richard E. Muncrief
Well, if you look at the total puds, if you look at Continental across the company in the Bakken, we've got just over about one in the third or so puds producing that well, and SCOOP worth about 2 puds per producing well. And so we've got, in both of the plays, we've got obviously a lot of resource there that we can book in the future. But obviously, one of the things that comes into play is what you can get done in a 5-year period. We got -- and that's something that we'll, obviously, always be addressing. But I do think that what you're going to see is, with increased reserve, booking out of per well basis across our company, you're going to see continued growth, and I think it that we're going to be in really, really good shape to meet our 5-year plan.
And we have no further questions at this time. I would now turn the call over to Mr. Harold Hamm for closing remarks.
Harold G. Hamm
Thanks Vanessa. Again, I'd like to thank everybody for joining us today on this conference call.
Continental delivered another very strong year in 2013, and we look forward to record achievements again next year.
By the way, you may have noticed, 2 new titles in introduction today, and I'll address those. Along with a number of other promotions here in the company last week. We have a John Kilgallon to the leadership role in Investor Relations. Warren Henry takes on a new challenge as VP of Research and Policy. He'll remain heavily involved, of course, with IR but he will also support public relations, governmental affairs and executive group with research and proposals for addressing state and federal issues such as transportation, exports, regulation and others that impact Continental's growth strategy. It's just a great fit for Warren's background, and John has proven he's already detective range in IR. I know our investors have very strong relationships with both Warren and John, so please feel free to call either them with your questions. They'll continue working together closely. That completes our call today. Thanks again, and we look forward to speaking with you again in early May.
And thank you, ladies and gentlemen. This concludes today's conference. Thank you for participating. You may now disconnect.
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It's in the hair.
Scientists at the University of Copenhagen have become the first to reconstruct the nuclear genome of an extinct human being. The reconstruction serves as blueprint that scientists can use to give a description of how the pre-historic Greenlander, Inuk, looked - including his tendency to baldness, dry earwax, brown eyes, dark skin, the blood type A+, shovel-shaped front teeth, and that he was genetically adapted to cold temperatures, and to what extend he was predisposed to certain illnesses.
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