Weatherford To Cut 5,000 Jobs -- February 5, 2015; 2015: The Year Of Cutbacks

Reuters at Rigzone is reporting:

Weatherford International Plc plans to cut 5,000 jobs, or about 9 percent of its workforce, by the end of the first quarter as the oil services company tries to save costs amid sinking oil prices and budget cuts. The job cuts will focus on both operating and support positions and a majority of the reductions will be in the Western Hemisphere, the company said in a statement.

Weatherford, which currently employs about 56,000 people across the world, expects the job cuts to result in annualized savings of over $350 million.

Add the Weatherford cuts to earlier announced cuts:

• more job cuts at banks seen in poll of investors, January 21, 2015
• big job cuts seen at DreamWorks, January 19, 2015
• 50,000 Wall Street jobs lost, January 17, 2015
• Microsoft will cut 18,000 jobs by June, 2015, July 7, 2014
• Governor Rick Scott cuts more state jobs than any other governor, January 17, 2015
• Coca-Cola to cut up to 1,800 jobs, January 8, 2015
• US Army could see 4,200 jobs cut at Ft Eustis, January 13, 2015
• Altisource Portfolio Solutions, Boston, layoffs hit, January 14, 2015
• USPS will shed 3,000 jobs by 2015, July 3, 2014
• Blytheville Mill to cut 300 jobs, January 9, 2015
• Carolinas Healthcare to book layoffs, January 22, 2015
• CHI Health foresees staff cuts early in 2015, but effect on Nebraska, Iowa not yet known, November 19, 2014 

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The Midnight Fugue Begins

All My Loving, Paul McCartney

$200 Oil -- February 5, 2015

The other day a Saudi spokesman suggested "we" could see $200 oil. I didn't link the article; I'm not even sure I read it. I don't spend much time reading what folks predict for oil prices; it seems to be a fool's errand, as they say.

Having said that, add this to the dots to connect when thinking about $200 oil (I might come back to this and write a bit more on what I wrote a reader with regard to $200 oil but this will have to do for now; I'm behind in all the news stories that start showing up after the midnight hour.

Reuters via Rigzone is reporting: Oil Majors Fail To Find Reserves To Counter Falling Output.

Big oil companies had a poor record of finding and producing oil and gas last year, according to figures out in the past week – and big cuts in spending in response to falling crude prices could undermine their plans to turn that around. Four of the world's six biggest oil firms by market value – Royal Dutch Shell, Chevron, BP and ConocoPhillips – released provisional figures showing together they replaced only two-thirds of the hydrocarbons they extracted in 2014 with new reserves.

Combined, those four and industry leader Exxon Mobil posted an average drop in oil and gas production of 3.25 percent last year. All predict their output will increase and new reserves will be added in coming years. But the 2014 results echo longer-term trends.

Then this:

The latest collapse has seen prices halve since June. In recent months, the biggest oil groups on both sides of the Atlantic have announced sharp cuts in capital expenditure (capex) out as far as 2017, as they seek to preserve cash to maintain dividends. Investors have largely welcomed the focus on dividends. But some say the cuts could come back to bite the industry. 

Much more at the link.

The Clock Is Ticking .... February 5, 2015

Reuters via Rigzone is reporting:

Tumbling crude oil prices have started the clock ticking on a potential $5.3 billion, two-year tax break for North Dakota's oil producers.

The countdown, which started this week, holds the promise of a silver lining of sorts for oil producers and their contractors in the No. 2 oil-producing U.S. state, many of whom have struggled with a roughly 50 percent drop in oil prices since last June.

North Dakota officials designed the tax waiver in 1987 to encourage drilling. Here's how it works:

North Dakota waives its 6.5 percent oil extraction tax if the monthly price of benchmark West Texas Intermediate (WTI) crude at the Cushing, Oklahoma, transport hub falls below $52.59 per barrel for five consecutive months.

For January 2015, the average price was $47.98 per barrel. "Since January prices were well below the required price for the large trigger, we are now in our first month," said Ryan Rauschenberger, North Dakota's tax commissioner.

The average monthly price has to be below the $52.59 level for each of the next four months. If it's off even one month, the clock resets.

The tax returns if the average price exceeds that level for a subsequent five consecutive months.

How much difference does the extraction tax make?

Rauschenberger estimates North Dakota will take in $2.9 billion in oil taxes in the next two years without the oil extraction tax. With the tax, the projection is $8.2 billion.

But already:

A mild incentive just took effect this week for new wells. The state will cut the oil extraction tax rate to 2 percent from 6.5 percent on the first 75,000 barrels of oil produced (or oil worth up to $4.5 million) on wells drilled between now and June, or until the oil price hits $72.50 per barrel. This short-term cut was designed to occur more frequently and offer a milder incentive than the larger, longer-lasting cut.

Update On EOG Well Permitted For Gas Injection (#16986); Update On EOG Well Approved For Water Injection (#17170) -- February 5, 2015

Updates

May 6, 2021: EOG's application -- stripper well determination.

• 16986, INJP/1,347, EOG, Parshall 20-03H, s1/08; t 5/08; AL; cum 309K 1/22; short horizontal.
  

Gas injection, began in 2014:

• 16986, INJP/1,347, EOG, Parshall 20-03H, s1/08; t 5/08; AL; cum 275K 11/17; short horizontal. 

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	9-2015	5	222	248	138	108	82	4
BAKKEN	8-2015	31	1714	1693	1001	957	531	271
BAKKEN	7-2015	31	1730	1722	1110	967	660	154
BAKKEN	6-2015	30	1681	1703	1136	896	641	105
BAKKEN	5-2015	31	1936	1919	1376	1004	767	82
BAKKEN	4-2015	26	1566	1560	1320	762	630	9
BAKKEN	3-2015	31	1962	1969	1773	970	471	344
BAKKEN	2-2015	28	1785	1814	1902	924	765	19
BAKKEN	1-2015	31	1473	1466	1700	887	647	85

• 17170, 667, EOG, Wayzetta 4-16H, Parshall, Bakken, s4/08; t7/08; cum 487K 11/17;-- pretty impressive -- now on pump; > 300K after first 3 years; a short lateral; 6 frack stages (?);

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	9-2015	30	2441	2353	396	1883	1606	94
BAKKEN	8-2015	31	2273	2378	267	2005	1393	422
BAKKEN	7-2015	30	2648	2557	500	1923	1740	7
BAKKEN	6-2015	30	2569	2567	634	1961	1674	103
BAKKEN	5-2015	31	2769	2771	308	2015	1825	0
BAKKEN	4-2015	30	2654	2738	464	1576	17	1375
BAKKEN	3-2015	31	3121	3033	387	1675	0	1485
BAKKEN	2-2015	28	2839	2788	538	1607	1122	313
BAKKEN	1-2015	31	3425	3496	481	1572	964	41

Original Post

This is an update of a well previously approved for water injection. In June, 2014, EOG requested approval for gas injection of this well.

• 16986, PWI/1,347, EOG, Parshall 20-03H, s1/08; t 5/08; AL; cum 258K 9/16; short horizontal.

Production profile since August, 2011:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	12-2014	4	10	0	0	9	0	0
BAKKEN	11-2014	8	374	349	241	174	159	0
BAKKEN	10-2014	26	1914	2121	1857	1313	1170	24
BAKKEN	9-2014	27	2569	2399	1365	2099	657	1314
BAKKEN	8-2014	0	0	0	0	0	0	0
BAKKEN	7-2014	0	0	0	0	0	0	0
BAKKEN	6-2014	25	1397	1561	3483	113	0	0
BAKKEN	5-2014	5	294	0	1051	1672	1656	0
BAKKEN	4-2014	4	18	0	89	16	0	0
BAKKEN	3-2014	12	59	0	851	60	0	0
BAKKEN	4-2012	13	0	0	0	58	0	0
BAKKEN	3-2012	30	1800	1843	219	2331	2186	0
BAKKEN	2-2012	29	2054	2136	245	2571	2426	0
BAKKEN	1-2012	31	2645	2583	301	2932	2777	0
BAKKEN	12-2011	31	2278	2251	298	2043	1888	0
BAKKEN	11-2011	19	1236	1260	275	1228	1140	0
BAKKEN	10-2011	31	2586	2617	299	2413	2127	131
BAKKEN	9-2011	30	1877	1884	240	1662	777	735
BAKKEN	8-2011	31	1932	1929	244	1693	726	812

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Completely unrelated, this is the production profile of an EOG well that was permitted for water injection in February, 2012.

• 17170, PWI/667, EOG, Wayzeta 4-16H, Parshall, Bakken, s4/08; t7/08; F; cum 461K 9/16; -- pretty impressive -- no pump; > 300K after first 3 years; a short lateral; 6 frack stages (?);

Production profile only since November, 2011, a couple months before water injection began. Note, also the jump in production in January, 2014. The well file did not suggest the reason.

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	12-2014	28	3287	3216	507	941	409	364
BAKKEN	11-2014	30	3766	3761	630	1384	968	232
BAKKEN	10-2014	31	4073	4668	576	1486	326	970
BAKKEN	9-2014	30	4214	3695	435	1559	6	1369
BAKKEN	8-2014	31	4615	4605	821	1697	4	1540
BAKKEN	7-2014	15	2073	2048	595	782	10	704
BAKKEN	6-2014	30	5842	6174	2023	2294	43	2101
BAKKEN	5-2014	31	5978	5615	2840	2461	1754	552
BAKKEN	4-2014	30	5815	5841	3343	2536	2041	345
BAKKEN	3-2014	31	5590	5564	3828	2589	2418	18
BAKKEN	2-2014	28	6172	6183	5954	2680	2420	121
BAKKEN	1-2014	31	7058	7089	8348	1894	878	861
BAKKEN	12-2013	2	84	198	989	68	6	52
BAKKEN	11-2013	0	0	0	0	0	0	0
BAKKEN	10-2013	0	0	0	0	0	0	0
BAKKEN	9-2013	15	2687	2546	1544	975	584	319
BAKKEN	8-2013	8	798	775	1028	476	209	230
BAKKEN	7-2013	16	1321	1237	282	434	354	0
BAKKEN	6-2013	26	2136	2361	722	879	751	0
BAKKEN	5-2013	29	2082	1840	952	917	778	0
BAKKEN	4-2013	30	1974	2031	1210	2536	2041	345
BAKKEN	3-2013	31	1869	1832	1620	816	661	0
BAKKEN	2-2013	28	1475	1586	2148	659	519	0
BAKKEN	1-2013	31	1558	1370	4637	569	416	0
BAKKEN	12-2012	7	37	0	1214	45	12	0
BAKKEN	11-2012	0	0	0	0	0	0	0
BAKKEN	10-2012	9	768	919	245	370	181	144
BAKKEN	9-2012	30	2462	2439	941	1192	1039	3
BAKKEN	8-2012	26	2243	2263	1152	963	846	0
BAKKEN	7-2012	31	1730	1757	1699	790	601	81
BAKKEN	6-2012	9	446	379	1216	133	90	0
BAKKEN	5-2012	0	0	0	0	0	0	0
BAKKEN	4-2012	22	2506	2522	77	1294	1184	0
BAKKEN	3-2012	31	4195	4229	204	2347	2192	0
BAKKEN	2-2012	9	1703	1639	32	776	732	0
BAKKEN	1-2012	30	3508	3505	104	2236	2091	0
BAKKEN	12-2011	28	3625	3614	103	2207	2067	0
BAKKEN	11-2011	30	3717	3728	113	2365	2215	0

Random Look At Statoil Cvancara Well That Was Re-Fracked Two Years Later; No Production In Between Fracks -- February 5, 2015

Updates

February 26, 2016: this well is back on-line; update here is quite extensive. 
 

Original Post

 

This is somewhat interesting. This Statoil Cvancara well is on a five-well pad. It is currently listed as IA at the NDIC website, but my hunch is that it is back on line and will be back on active status within the next month or so. Note the production profile for this well:

21957, 1,779, Statoil, Cvancara 20-17 4TFH, t7/14; cum 17K 12/14;

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	12-2014	25	13778	13155	27258	0	0	0
BAKKEN	11-2014	0	0	3	0	0	0	0
BAKKEN	10-2014	4	44	62	6	145	0	145
BAKKEN	9-2014	30	41	20	1142	15	11	4
BAKKEN	8-2014	31	0	30	0	0	0	0
BAKKEN	7-2014	31	3340	3310	42761	2824	1810	1014

This well was originally fracked 8/31/12: 5 stages; 534,092 lbs of proppant (sand + ceramic); obviously something went wrong with the frack or they were simply seeing what 5 stages would do (I doubt it) -- at the time of the application, they were planning on 33 swell packers to complete the well.

They came back and re-fracked on 6/11/2014: 35 stages; 3.3 million lbs proppants
(again, sand + ceramic).

Even though it was re-fracked in July, 2014, the well did not reach significant production until several months later, December, 2014. There may have been operational reasons -- there are four other wells on that pad and another multi-well pad in the immediate area.